Patent Grant
7222676
1. Field of Invention
The present invention relates to the field of well monitoring. More specifically, the invention relates to well equipment and methods utilizing control line systems for monitoring of wells and for well telemetry.
2. Related Art
There is a continuing need to improve the efficiency of producing hydrocarbons and water from wells. One method to improve such efficiency is to provide monitoring of the well so that, for example, adjustments may be made to improve well efficiency. Accordingly, there is a continuing need to provide such systems.
Embodiments of the present invention provide systems and methods for use in connection with wells. The systems and methods utilize monitoring and telemetry to facilitate various well treatments, data gathering and other well based operations.
The manner in which these objectives and other desirable characteristics can be obtained is explained in the following description and attached drawings in which:
It is to be noted, however, that the appended drawings illustrate only embodiments of this invention and are therefore not to be considered limiting of its scope, for the invention may admit to other equally effective embodiments.
In the following description, numerous details are set forth to provide an understanding of the present invention. However, it will be understood by those skilled in the art that the present invention may be practiced without these details and that numerous variations or modifications from the described embodiments may be possible.
In this description, the terms “up” and “down”; “upward” and downward”; “upstream” and “downstream”; and other like terms indicating relative positions above or below a given point or element are used in this description to more clearly described some embodiments of the invention. However, when applied to apparatus and methods for use in wells that are deviated or horizontal, such terms may refer to a left to right, right to left, or other relationship as appropriate.
One aspect of the present invention is the use of a sensor, such as a fiber optic distributed temperature sensor, in a well to monitor an operation performed in the well, such as a gravel pack as well as production from the well. Other aspects comprise the routing of control lines and sensor placement in a sand control completion. Referring to the attached drawings,
The present invention can be utilized in both cased wells and open hole completions. For ease of illustration of the relative positions of the producing zones, a cased well having perforations will be shown.
In the illustrated sand control completion, the well tool 20 comprises a tubular member 22 attached to a production packer 24, a cross-over 26, and one or more screen elements 28. The tubular member 22 can also be referred to as a tubing string, coiled tubing, workstring or other terms well known in the art. Blank sections 32 of pipe may be used to properly space the relative positions of each of the components. An annulus area 34 is created between each of the components and the wellbore casing 16. The combination of the well tool 20 and the tubular string extending from the well tool to the surface can be referred to as the production string.
In a gravel pack operation the packer element 24 is set to ensure a seal between the tubular member 22 and the casing 16. Gravel laden slurry is pumped down the tubular member 22, exits the tubular member through ports in the cross-over 26 and enters the annulus area 34. Slurry dehydration occurs when the carrier fluid leaves the slurry. The carrier fluid can leave the slurry by way of the perforations 18 and enter the formation 14. The carrier fluid can also leave the slurry by way of the screen elements 28 and enter the tubular member 22. The carrier fluid flows up through the tubular member 22 until the cross-over 26 places it in the annulus area 36 above the production packer 24 where it can leave the wellbore 10 at the surface. Upon slurry dehydration the gravel grains should pack tightly together. The final gravel filled annulus area is referred to as a gravel pack. In this example, an upper zone 38 and a lower zone 40 are each perforated and gravel packed. An isolation packer 42 is set between them.
As used herein, the term “screen” refers to wire wrapped screens, mechanical type screens and other filtering mechanisms typically employed with sand screens. Screens generally have a perforated base pipe with a filter media (e.g., wire wrapping, mesh material, pre-packs, multiple layers, woven mesh, sintered mesh, foil material, wrap-around slotted sheet, wrap-around perforated sheet, MESHRITE manufactured by Schlumberger, or a combination of any of these media to create a composite filter media and the like) disposed thereon to provide the necessary filtering. The filter media may be made in any known manner (e.g., laser cutting, water jet cutting and many other methods). Sand screens have openings small enough to restrict gravel flow, often having gaps in the 60–120 mesh range, but other sizes may be used. The screen element 28 can be referred to as a screen, sand screen, or a gravel pack screen. Many of the common screen types include a spacer that offsets the screen member from a perforated base tubular, or base pipe, that the screen member surrounds. The spacer provides a fluid flow annulus between the screen member and the base tubular. Screens of various types are commonly known to those skilled in the art. Note that other types of screens will be discussed in the following description. Also, it is understood that the use of other types of base pipes, e.g. slotted pipe, remains within the scope of the present invention. In addition, some screens 28 have base pipes that are imperforated along their length or a portion thereof to provide for routing of fluid in various manners and for other reasons.
Note that numerous other types of sand control completions and gravel pack operations are possible and the above described completion and operation are provided for illustration purposes only. As an example,
Similarly,
In each of the examples shown in
Examples of control lines 60 are electrical, hydraulic, fiber optic and combinations of thereof. Note that the communication provided by the control lines 60 may be with downhole controllers rather than with the surface and the telemetry may include wireless devices and other telemetry devices such as inductive couplers and acoustic devices. In addition, the control line itself may comprise an intelligent completions device as in the example of a fiber optic line that provides functionality, such as temperature measurement (as in a distributed temperature system), pressure measurement, sand detection, seismic measurement, and the like.
Examples of intelligent completions devices that may be used in the connection with the present invention are gauges, sensors, valves, sampling devices, a device used in intelligent or smart well completion, temperature sensors, pressure sensors, flow-control devices, flow rate measurement devices, oil/water/gas ratio measurement devices, scale detectors, actuators, locks, release mechanisms, equipment sensors (e.g., vibration sensors), sand detection sensors, water detection sensors, data recorders, viscosity sensors, density sensors, bubble point sensors, pH meters, multiphase flow meters, acoustic sand detectors, solid detectors, composition sensors, resistivity array devices and sensors, acoustic devices and sensors, other telemetry devices, near infrared sensors, gamma ray detectors, H2S detectors, CO2 detectors, downhole memory units, downhole controllers, perforating devices, shape charges, firing heads, locators, and other downhole devices. In addition, the control line itself may comprise an intelligent completions device as mentioned above. In one example, the fiber optic line provides a distributed temperature functionality so that the temperature along the length of the fiber optic line may be determined.
In the embodiment shown in
The shroud 74 comprises at least one channel 82 therein. The channel 82 is an indented area in the shroud 74 that extends along its length linearly, helically, or in other traversing paths. The channel 82 in one alternative embodiment has a depth sufficient to accommodate a control line 60 therein and allow the control line 60 to not extend beyond the outer diameter of the shroud 74. Other alternative embodiments may allow a portion of the control line 60 to extend from the channel 82 and beyond the outer diameter of the shroud 74 without damaging the control line 60. In another alternative, the channel 82 includes an outer cover (not shown) that encloses at least a portion of the channel 82. To protect the control line 60 and maintain it in the channel 82, the sand screen 28 may comprise one or more cable protectors, or restraining elements, or clips.
The control line 60 may extend the full length of the screen 28 or a portion thereof. Additionally, the control line 60 may extend linearly along the screen 28 or follow an arcuate path.
In both
Likewise,
In the alternative embodiment of
In addition to conventional sand screen completions, the present invention is also useful in completions that use expandable tubing and expandable sand screens. As used herein an expandable tubing 90 comprises a length of expandable tubing. The expandable tubing 90 may be a solid expandable tubing, a slotted expandable tubing, an expandable sand screen, or any other type of expandable conduit. Examples of expandable tubing are the expandable slotted liner type disclosed in U.S. Pat. No. 5,366,012, issued Nov. 22, 1994 to Lohbeck, the folded tubing types of U.S. Pat. No. 3,489,220, issued Jan. 13, 1970 to Kinley, U.S. Pat. No. 5,337,823, issued Aug. 16, 1994 to Nobileau, U.S. Pat. No. 3,203,451, issued Aug. 31, 1965 to Vincent, the expandable sand screens disclosed in U.S. Pat. No. 5,901,789, issued May 11, 1999 to Donnelly et al., U.S. Pat. No. 6,263,966, issued Jul. 24, 2001 to Haut et al., PCT Application No. WO 01/20125 A1, published Mar. 22, 2001, U.S. Pat. No. 6,263,972, issued Jul. 24, 2001 to Richard et al., as well as the bi-stable cell type expandable tubing disclosed in U.S. patent application Ser. No. 09/973,442, filed Oct. 9, 2001. Each length of expandable tubing may be a single joint or multiple joints.
Referring to
In addition, the control line 60 or intelligent completions device 62 provided in the expandable tubing may be used to measure well treatments (e.g., gravel pack, chemical injection, cementing) provided through or around the expandable tubing 90.
In one embodiment the expandable tubing sections 90 are expandable sand screens and the expandable completion provides a sand face completion with zonal isolation. The expandable tubing sections and the unexpanded tubing sections may be referred to generally as an outer conduit or outer completion. In the embodiment of
Note that the control line 60 may comprise a fiber optic line that provides functionality and facilitates measurement of flow and monitoring of treatment and production. Although shown as extending between the inner and outer completions, the control line 60 may extend outside the outer completions or internal to the components of the completions equipment.
As one example of an expandable screen 90,
In addition to the primary screens 28 and expandable tubing 90, the control lines 60 also pass through connectors 120 for these components. For expandable tubing 90, the connector 120 may be formed similar to the tubing itself in that the control line may be routed in a manner as described above.
One difficulty in routing control lines through adjacent components involves achieving proper alignment of the portions of the control lines 60. For example, if the adjacent components are threaded it is difficult to ensure that the passageway through one components will align with the passageway in the adjacent component. One manner of accomplishing proper alignment is to use a timed thread on the components that will stop at a predetermined alignment and ensure alignment of the passageways. Another method of ensuring alignment is to form the passageways after the components have been connected. For example, the control line 60 may be clamped to the outside of the components. However, such an arrangement does not provide for the use of passageways or grooves formed in the components themselves and may require a greater time and cost for installation. Another embodiment that does allow for incorporation of passageways in the components uses some form of non-rotating connection.
One type of non-rotating connector 120 is shown in
Another type of non-rotating connection is a snap fit connection 130. As best seen in
In one embodiment, a control line passageway is defined in the well. Using one of the routing techniques and equipment previously described. A fiber optic line is subsequently deployed through the passageway (e.g., as shown in U.S. Pat. No. 5,804,713). Thus, in an example in which the non-rotating couplings 120 are used, the fiber optic line is blown through the aligned passageways formed by the non-rotating connections. Timed threads may be used in the place of the non-rotating connector.
Often, a connection must be made downhole. For a conventional type control line 60, the connection may be made by stabbing an upper control line connector portion into a lower control line connector portion. However, in the case of a fiber optic line that is “blown” into the well through a passageway, such a connection is not possible. Thus, in one embodiment (shown in
In one exemplary operation, a completion having a fiber optic control line 60 is placed in the well. The fiber optic line extends through the region to be gravel packed (e.g., through a portion of the screen 28 as shown in the figures). A service tool is run into the well and a gravel pack slurry is injected into the well using a standard gravel pack procedure as previously described. The temperature is monitored using the fiber optic line during the gravel pack operation to determine the placement of the gravel in the well. Note that in one embodiment, the gravel is maintained at a first temperature (e.g., ambient surface temperature) before injection into the well. The temperature in the well where the gravel is to be placed is at a second temperature that is higher than the first temperature. The gravel slurry is then injected into the well at a sufficient rate that it reaches the gravel pack area before its temperature rises to the second temperature. The temperature measurements provided by the fiber optic line are thus able to demonstrate the placement of the gravel in the well.
If it is determined that a proper pack has not been achieved, remedial action may be taken. In one embodiment, the gravel packed zone has an isolation sleeve, intelligent completions valve, or isolation valve therein that allows the zone to be isolated from production. Thus, if a proper gravel pack is not achieved, the remedial action may be to isolate the zone from production. Other remedial action may comprise injecting more material into the well.
In an alternative embodiment, sensors are used to measure the temperature. In yet another alternative embodiment, the fiber optic line or sensors are used to measure the pressure, flow rate, or sand detection. For example, if sand is detected during production, the operator may take remedial action (e.g., isolating or shutting in the zone producing the sand). In another embodiment, the sensors or fiber optic line measure the stress and/or strain on the completion equipment (e.g., the sand screen 28) as described above. The stress and strain measurements are then used to determine the compaction of the gravel pack. If the gravel pack is not sufficient, remedial action may be taken.
In another embodiment, a completion having a fiber optic line 60 (or one or more sensors) is placed in a well. A proppant is heated prior to injection into the well. While the proppant is injected into the well, the temperature is measured to determine the placement of the proppant. In an alternative embodiment the proppant has an initial temperature that is lower than the well temperature.
Similarly, the fiber optic line 60 or sensors 62 may be used to determine the placement of a fracturing treatment, chemical treatment, cement, or other well treatment by measuring the temperature or other well characteristic during the injection of the fluid into the well. The temperature may be measured during a strip rate test in like manner. In each case remedial action may be taken if the desired results are not achieved (e.g., injecting additional material into the well, performing an additional operation). It should be noted that in one embodiment, a surface pump communicates with a source of material to be placed in the well. The pump pumps the material from the source into the well. Further, the intelligent completions device (e.g., sensor, fiber optic line) in the well may be connected to a controller that receives the data from the intelligent completions device and provides an indication of the placement position using that data. In one example, the indication may be a display of the temperature at various positions in the well.
Referring now to
As shown in the figures, a control line 60 extends along the outside of the completion. Note that other control line routing may be used as previously described. In addition, a control line 60 or intelligent completions device 62 is positioned in the service tool 164. In one embodiment, the service tool 164 comprises a fiber optic line 60 extending along at least a portion of the length of the service tool 164. As with the routing of the control line 60 in a screen 28, the control line 60 may extend along a helical or other non-linear path along the service tool 164.
In one embodiment the fiber optic line in the service tool 164 is used to measure the temperature during the gravel packing operation. As an example, this measurement may be compared to a measurement of a fiber optic line 60 positioned in the completion to better determine the placement of the gravel pack. The fiber optic lines 60 may comprise or be replaced by one or more sensors 62. For example, the service tool 164 may have a temperature sensor at the outlet 168 that provides a temperature reading of the gravel slurry as it exits the service tool. Other types of service tools (e.g., a service tool for fracturing, delivering a proppant, delivering a chemical treatment, cement, etc.) may also employ a fiber optic line or sensor therein as described in connection with the gravel pack service tool 164.
In each of the monitoring embodiments above, a controller may be used to monitor the measurements and provide an interpretation or display of the results.
Once the plug 176 is in the wet connect sub 174, the operative connection between the fiber optic line 60 extending to the washpipe and the fiber optic line 60 extending to the surface is made, and real-time temperature data can be monitored through the fiber optic line 60. As shown in
In one embodiment, the wet connect sub 174 has an inside diameter that is sufficiently large that packer setting balls may pass through. It also has a profile in which the plug 176 may located (although he locating function may be spaced from the fiber optic wet connect function). In addition, at the time plug 176 is located, bypass area is allowed in this sub so as not to prevent the flow of fluids down the workstring, past the sub 174, and through the FOCT 178. The wet connect sub 174 also contains one half of a wet connection. The second half of the wet connection is incorporated in the plug 176.
The plug is transported in the well on a conveyance device such as a slickline, wireline, or tubing, that provides a fiber optic line. This fiber optic line is connected to the plug which has a fiber optic conduit connecting the fiber optic line to the second half of the wet connect. When the plug is landed in the sub 174 profile, a fiber optic connection is made and allows the measurement of the temperature (or other well parameters) with the entire fiber optic line, through the wet connect sub, through the FOCT and along the fiber optic placed in and/or along the washpipe. The temperature data, for example, is gathered and used in real time to monitor the flow of fluid during the gravel pack and to thereby allow real time adjustments to the gravel pack operation.
Referring generally to
After placing liner 188 in the wellbore, the wet connect tool 180 is run into the well, as illustrated in
In an alternate embodiment, as illustrated in
In one exemplary application, a lower completion having a fiber optic instrumented sand screen, a packer, a service tool and a polished bore receptacle is run in hole. A fiber optic cable is terminated in the receptacle which contains one side of a fiber optic wet mateable connector. A dry-mate fiber optic connection may be utilized on an opposite end of the wet-mate connector.
Once the lower completion is in place, normal gravel packing operations can be performed beginning with setting of the packer and the service tool. Once the packer is tested, the service tool is released from the packer and shifted to another position to enable pumping of the gravel. Upon pumping of sufficient gravel, a screen out may be observed, and the service tool is shifted to another position to reverse out excess gravel. The service tool may then be pulled out of the wellbore. It should be noted that the service string carrying the service tool also can have a fiber optic line and/or plugable connector as well. This would allow use of the fiber optic line during the gravel pack or other service operation.
Subsequently, a dip tube is run in hole on the bottom of a production tubing with a fiber optic cable attached. The dip tube contains the other mating portion of the fiber optic wet-mate connection. It also may use a dry-mate connection on an opposite end to join with the fiber optic cable segment extending to the surface. The dip tube lands in the receptacle, and production seals are stabbed into a seal bore in the receptacle. The hardware containing the fiber wet-mate connector may be aligned by alignment systems as the connector portions are mated. During the last few inches of the mating stroke, a snap latch may be mated, and the fiber optic connection may be completed in a sealed, clean, oil environment. This is one example of an intelligent control line system that may be connected and implemented at a down hole location. Other embodiments of down hole control line systems are described below.
Referring generally to
Lower completion 202 may comprise a variety of components. For example, the lower completion may comprise a packer 208, a formation isolation valve 210 and a screen 211, such as a base pipe screen. Formation isolation valve 210 may be selectively closed and opened by pressure pulses, electrical control signals or other types of control inputs. By way of example, valve 210 may be selectively closed to set packer 208 via pressurization of the system. In some applications, formation isolation valve 210 may be designed to close automatically after gravel packing. However, the valve 210 is subsequently opened to enable the insertion of dip tube 206.
In the embodiment illustrated, upper completion 204 includes a packer 212 and a side pocket sub 214, which may comprise a connection feature 216, such as a wet connect. Packer 212 and side pocket sub 214 may be mounted on tubing 218. Additionally, the lower completion 202 and upper completion 204 may be designed with a gap 220 therebetween such that there is no fixed point connection. By utilizing gap 220 between the lower and upper completions, a “space out” trip into the well to measure tubing 218 is not necessary. As a result, the time and cost of the operation is substantially reduced by eliminating the extra out trip down hole.
Upon placement of lower completion 202 and upper completion 204, dip tube 206 is run through tubing 218 on, for example, coiled tubing or a wireline. Dip tube 206 comprises a corresponding connection feature 222, such as a wet connect mandrel 224 that engages connection feature 216.
In the embodiment illustrated, engagement of connection feature 216 and corresponding connection feature 222 forms a wet connect by which a lower control line 226, disposed in dip tube 206, is coupled with an upper control line 228, disposed on upper completion 204, to form an overall control line 230. Control line 230 may be a single control line or multiple control lines. Additionally, control line 230 may comprise tubing for conducting hydraulic control signals or chemicals, an electrical control line, fiber optic control line or other types of control lines. The overall control line system 201 is particularly amenable to use with control lines such as fiber optic control lines that may incorporate or be combined with sensors such as distributed temperature sensors 232. In some embodiments, connection feature 216 and corresponding connection feature 222 of system 200 comprise a hydraulic wet connect. With a hydraulic wet connect, system 200 may further comprise a fiber optic or other signal carrier that is subsequently inserted through the tubing by, for example, blowing the signal conductor through the tubing.
In another embodiment illustrated in
Another embodiment of system 200 is illustrated in
Referring generally to
In this embodiment, the control line 230 comprises a coiled section 244 to reduce or eliminate stress on control line 230 during expansion or contraction of joint 242. Control line 230 may comprise a variety of control lines, including hydraulic lines, chemical injection lines, electrical lines, fiber optic control lines, etc. In the example illustrated, control line 230 comprises a fiber optic control line having an upper section 246 coupled to coiled section 244 by a fiber optic splice 248. Coiled section 244 is connected to a lower control line section 250 by a connector 252, such as a fiber optic wet connect 254 and latch 256. Thus, the overall control line 230 is formed when upper completion 204, including expansion joint 242 and coiled section 244, is coupled to lower completion 202. As illustrated, lower control line section 250 may be deployed externally to screen 211 and may deploy a variety of sensors, e.g., a distributed temperature sensor.
Another embodiment of system 200 is illustrated in
In operation, the entire completion 258 along with control line 230 is run into the wellbore in a single trip. The system is landed out on a tubing hanger “not shown”, and a control signal, such as a pressure pulse, is sent to close ball valve 260. Subsequently, the interior of tubing 218 is pressurized sufficiently to set the screen hanger packer, packer 208, via a separate control line 266. Next, a screen expander tool is run through tubing 218 on a work string. Valve 260 is then opened by, for example, a pressure pulse or other command signal or by running a shifting tool at the end of the screen expander tool. The screen expander is then moved through screen 211 to transition the screen to its expanded state, illustrated in
Upon expansion of the screen, the expanding tool is pulled out of the wellbore, and the valve 260 is closed with, for example, a shifting tool at the end of the screen expander. Once the expander tool is removed from the wellbore, a pressure pulse or other appropriate command signal is sent down hole to open circulating valve 262 via, for example, a sliding sleeve 268. The fluid in tubing 218 is then displaced with a completion fluid, such as a lighter fluid or a thermal insulation fluid. Subsequently, the valve is closed to permit pressure buildup within tubing 218. The pressure is increased sufficiently to set upper packer 212. Then, a pressure pulse or other appropriate command signal is sent down hole to open valve 260. At this stage, the entire completion 258 is set at a desired location within the wellbore along with control line 230. Furthermore, the entire procedure only involved a single trip down hole.
An embodiment similar to that of
Another embodiment of system 200 is illustrated in
Above packer 282, a larger tubing 290 encircles tubing 286 and is coupled to a screen, such as a base pipe screen 292. Screen 292 allows fluid from wellbore zone 278 to enter the annulus between tubing 286 and larger tubing 290. Larger tubing 290 extends to a packer 294 deployed generally at an upper region of wellbore zone 278 to isolate wellbore zone 278. Additionally, a port closure sleeve 296 and a flow isolation valve 298 may be deployed between screen 292 and packer 294.
A dip tube 300 incorporating a control line extends into wellbore zone 278 intermediate tubing 286 and larger tubing 290. An additional dip tube 302 having, for example, a fiber optic control line, is deployed through tubing 286 into the lower wellbore zone 280. Each of the dip tubes 300 and 302 may be deployed according to methods described above with respect to
In
Another embodiment of a system 200 is illustrated in
Initially, packer 322 and expandable sand screen 324 are positioned in the wellbore, and sand screen 324 is expanded. Subsequently, upper completion 204 along with one or more control lines 230 is run in hole and latched to latch member 326. In this embodiment, upper completion 204 may comprise a snap latch assembly 328 for coupling to latch member 326. Additionally, upper completion 204 comprises a formation isolation valve 330, a control line coiled section 332, a space out contraction/expansion joint 334, a tubing isolation valve 336 and an upper packer 338 all mounted to tubing 340.
The control line or lines 230 extend through upper packer 338 to coil section, 332 where the control lines are coiled to accommodate lineal contraction or expansion of joint 334. From coil section 332, the control line or lines 230 extend around formation isolation valve 330 and through snap latch assembly 328 to a dip tube 342 extending into sand screen 324.
With this design, the formation isolation valve 330 may be in a closed position subsequent to latching upper completion 204 to lower completion 202. This allows for deployment of control lines 230 and dip tube 342 prior to, for example, changing fluid in tubing 340, a procedure that requires closure of formation isolation valve 330. The upper tubing isolation valve 336 enables the selective setting of upper packer 338 prior to opening tubing 340. Thus, the entire upper completion and control line 230 along with dip tube 342 can be deployed in a single trip without the formation of any control line wet connects.
In
Referring generally to
Upon placement of anchor packer 350, the upper section of the completion may be run in hole. The upper completion is connected to a tubing 360 and comprises a packer 362. A tubing isolation valve 364 is position below packer 362, and a space out contraction/expansion joint 366 is located below valve 364. Control line 230 is coupled to a control line coil section 368 and terminates at a corresponding wet connect member 370. The corresponding wet connect member 370 is designed and positioned to pluggably engage connector member 354 to form a wet connect.
A similar embodiment is illustrated in
Referring generally to
Many intelligent completion systems may benefit from a moveable dip tube. For example, when running into deviated wells, a pivotable dip tube design may be utilized, as illustrated in
Referring generally to
Although fishing feature 420 and dip tube 414 may be utilized in a variety of applications, an exemplary application utilizes a flow shroud 424 connected between tubing 422 and a lower segment tubing or sand screen 426. A completion packer 428 is disposed about tubing 426, and dip tube 414 extends into tubing 426 through completion packer 428. In this embodiment, fluid flow typically moves upwardly through tubing 426 into the annulus between flow shroud 424 and in internal mounting mechanism 430 to which retrievable plug 418 is mounted. Mounting mechanism 430 comprises an opening 432 through which dip tube 414 passes and a plurality of flow ports 434 that communicate between the surrounding annulus and the interior of tubing 422. Thus, retrievable plug 418 and dip tube 414 can readily be retrieved through tubing 422 without obstructing fluid flow from tubing 426 to tubing 422.
Furthermore, connector 416 may comprise a variety of connectors, depending on the particular application. For example, the connector may comprise a hydraulic connector for the connection of tubing, or the connector may comprise a fiber optic wet connect or other control line wet connect. These and other types of connectors can be utilized depending on the specific application of the system.
With reference to
A variety of connection features may be incorporated into the overall design depending on the particular application. For example, a hydraulic wet connection feature 442 may be pivotably mounted within retrievable plug 418. In this particular embodiment, the hydraulic wet connection feature 442 is connected to a lower section 444 of control line 230, and the connection feature 442 is pivotably mounted within retrievable plug 418 for pivotable outward motion upon reaching a desired location. For example, when retrievable plug 418 is fully inserted into mounting mechanism 430, as illustrated in
Referring generally to
In this embodiment, upper completion 454 comprises a stinger 466 having a stinger collet 468 at a lead end. A fiber optic cable accumulator 470 is deployed at an end of stinger 466 generally opposite stinger collet 468. In this design, stinger 466 is rotatably coupled to fiber optic accumulator 470. In one embodiment, stinger 466 is rotationally locked with respect to fiber optic cable accumulator as the upper completion is moved downhole, but upon entry of stinger 466 into open receiving end 462, a release lever 472 (see
By way of specific example, alignment system 456 may comprise a helical cut 474 formed on open receiving end 462. An alignment key 476 is coupled to stinger 466, and is guided along helical cut 474 and into an internal groove 478 formed along the interior of receptacle assembly 458. Internal groove 478 guides alignment key 476 and stinger 466 as the upper completion 454 and lower completion 452 are moved towards full engagement.
As the insertion of stinger 466 continues towards completion, a fine alignment system 480 moves fiber optic connectors into engagement, as best illustrated in
Although only a few exemplary embodiments of this invention have been described in detail above, those skilled in the art will readily appreciate that many modifications are possible in the exemplary embodiments without materially departing from the novel teachings and advantages of this invention. Accordingly, all such modifications are intended to be included within the scope of this invention as defined in the following claims. In the claims, means-plus-function clauses are intended to cover the structures described herein as performing the recited function and not only structural equivalents, but also equivalent structures. Thus, although a nail and a screw may not be structural equivalents in that a nail employs a cylindrical surface to secure wooden parts together, whereas a screw employs a helical surface, in the environment of fastening wooden parts, a nail and a screw may be equivalent structures. It is the express intention of the applicant not to invoke 35 U.S.C. § 112, paragraph 6 for any limitations of any of the claims herein, except for those in which the claim expressly uses the words ‘means for’ together with an associated function.
This is a continuation-in-part of U.S. Ser. No. 10/125,447, filed Apr. 18, 2002 now U.S. Pat. No. 6,789,510 which was a continuation-in-part of U.S. Ser. No. 10/021,724 filed Dec. 12, 2001 now U.S. Pat. No. 6,695,054; U.S. Ser. No. 10/079,670, filed Feb. 20, 2002 now U.S. Pat. No. 6,848,510; U.S. Ser. No. 09/981,072, filed Oct. 16, 2001; U.S. Ser. No. 09/973,442, filed Oct. 9, 2001 now U.S. Pat. No. 6,799,637; U.S. Ser. No. 09/732,134, filed Dec. 7, 2000 now U.S. Pat. No. 6,446,729. The present application also is based upon and claims priority to U.S. provisional application Ser. No. 60/432,343, filed Dec. 10, 2002; U.S. Provisional application Ser. No. 60/418,487, filed Oct. 15, 2002; and U.S. provisional application Ser. No. 60/407,078, field Aug. 30, 2002.
| Number | Name | Date | Kind |
|---|---|---|---|
| 3864970 | Bell | Feb 1975 | A |
| 4375164 | Dodge et al. | Mar 1983 | A |
| 4783995 | Michel et al. | Nov 1988 | A |
| 4945991 | Jones | Aug 1990 | A |
| 4976142 | Perales | Dec 1990 | A |
| 5163321 | Perales | Nov 1992 | A |
| 5186255 | Corey | Feb 1993 | A |
| 5350018 | Sorem et al. | Sep 1994 | A |
| 5485745 | Rademaker et al. | Jan 1996 | A |
| 5515915 | Jones et al. | May 1996 | A |
| 5517593 | Nenniger et al. | May 1996 | A |
| 5579842 | Riley | Dec 1996 | A |
| 5690171 | Winch et al. | Nov 1997 | A |
| 5844927 | Kringlebotn | Dec 1998 | A |
| 5890533 | Jones | Apr 1999 | A |
| 5925879 | Hay | Jul 1999 | A |
| 5938925 | Hamid et al. | Aug 1999 | A |
| 6041860 | Nazzal et al. | Mar 2000 | A |
| 6065535 | Ross | May 2000 | A |
| 6065538 | Reimers et al. | May 2000 | A |
| 6125933 | Ross | Oct 2000 | A |
| 6173788 | Lembcke et al. | Jan 2001 | B1 |
| 6186229 | Martin et al. | Feb 2001 | B1 |
| 6192983 | Neuroth et al. | Feb 2001 | B1 |
| 6209640 | Reimers et al. | Apr 2001 | B1 |
| 6220353 | Foster et al. | Apr 2001 | B1 |
| 6253856 | Ingram et al. | Jul 2001 | B1 |
| 6279392 | Shahin, Jr. et al. | Aug 2001 | B1 |
| 6281489 | Tubel et al. | Aug 2001 | B1 |
| 6292066 | Shibuya et al. | Sep 2001 | B1 |
| 6296056 | Ward | Oct 2001 | B1 |
| 6302204 | Reimers et al. | Oct 2001 | B1 |
| 6325146 | Ringgenberg et al. | Dec 2001 | B1 |
| 6343651 | Bixenman | Feb 2002 | B1 |
| 6359569 | Beck et al. | Mar 2002 | B2 |
| 6446729 | Bixenman et al. | Sep 2002 | B1 |
| 6505682 | Brockman | Jan 2003 | B2 |
| 6513599 | Bixenman et al. | Feb 2003 | B1 |
| 20010020675 | Tubel et al. | Sep 2001 | A1 |
| 20020007948 | Bayne et al. | Jan 2002 | A1 |
| 20030196820 | Patel | Oct 2003 | A1 |
| 20050044690 | Gillespie et al. | Mar 2005 | A1 |
| Number | Date | Country |
|---|---|---|
| 2355740 | Feb 2001 | GB |
| WO 9850673 | Nov 1998 | WO |
| WO 9850680 | Nov 1998 | WO |
| WO9945235 | Sep 1999 | WO |
| WO 0133032 | May 2001 | WO |
| WO 0165067 | Sep 2001 | WO |
| WO0192680 | Dec 2001 | WO |
| WO0206593 | Jan 2002 | WO |
| WO0206625 | Jan 2002 | WO |
| Number | Date | Country | |
|---|---|---|---|
| 20030221829 A1 | Dec 2003 | US |
| Number | Date | Country | |
|---|---|---|---|
| 60407078 | Aug 2002 | US | |
| 60418487 | Oct 2002 | US | |
| 60432343 | Dec 2002 | US |
| Number | Date | Country | |
|---|---|---|---|
| Parent | 10125447 | Apr 2002 | US |
| Child | 10431284 | US | |
| Parent | 10021724 | Dec 2001 | US |
| Child | 10125447 | US | |
| Parent | 10079670 | Feb 2002 | US |
| Child | 10021724 | US | |
| Parent | 09981072 | Oct 2001 | US |
| Child | 10079670 | US | |
| Parent | 09973442 | Oct 2001 | US |
| Child | 09981072 | US | |
| Parent | 09732134 | Dec 2000 | US |
| Child | 09973442 | US |
