Abstract:
A well system utilizes a control line system. The control line system is implemented with a completion of the type deployed in a wellbore. The control line system facilitates transmission of monitoring, command or other types of control and telemetry. It is emphasized that this abstract is provided to comply with the rules requiring an abstract which will allow a searcher or other reader to quickly ascertain the subject matter of the technical disclosure. It is submitted with the understanding that it will not be used to interpret or limit the scope or meaning of the claims. 37 CFR 1.72(b).

Description:
CROSS-REFERENCE TO RELATED APPLICATION 
   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. 

   BACKGROUND 
   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. 
   SUMMARY 
   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. 

   
     BRIEF DESCRIPTION OF THE DRAWINGS 
     The manner in which these objectives and other desirable characteristics can be obtained is explained in the following description and attached drawings in which: 
       FIG. 1  illustrates a well having a gravel pack completion with a control line therein; 
       FIG. 2  illustrates a multilateral well having a gravel packed lateral and control lines extending into both laterals; 
       FIG. 3  illustrates a multilateral well having a plurality of zones in one of the laterals and sand face completions with control lines extending therein; 
       FIG. 4  is a cross sectional view of a sand screen used in an embodiment of the present invention; 
       FIG. 5  is a side elevational view of a sand screen showing a helical routing of a control line along the sand screen; 
       FIGS. 6 through 8  are cross sectional views of a sand screen showing numerous alternative designs; 
       FIGS. 9 and 10  illustrate wells having expandable tubings and control lines therein; 
       FIGS. 11 and 12  are cross sectional views of an expandable tubing showing numerous alternative designs; 
       FIGS. 13 through 15  illustrate alternative embodiments of connectors; and 
       FIG. 16  illustrates an embodiment of a wet connect. 
       FIGS. 17A–C  illustrate an example of a service tool according to an embodiment of the present invention; 
       FIGS. 18A–D  illustrate another embodiment of the service tool illustrated in  FIG. 17 ; 
       FIGS. 19A–C  illustrate an embodiment of a control line system having a wet connect, according to an embodiment of the present invention; 
       FIG. 20  is a schematic, cross-sectional view of an embodiment of a control line system according to one embodiment of the present invention; 
       FIG. 21  illustrates an alternate embodiment of the control line system illustrated in  FIG. 20 ; 
       FIG. 22  illustrates another alternate embodiment of the control line system illustrated in  FIG. 20 ; 
       FIG. 23  illustrates another embodiment of the control line system illustrated in  FIG. 20 ; 
       FIG. 24  illustrates another embodiment of the control line system illustrated in  FIG. 20 ; 
       FIG. 25  is a view similar to  FIG. 24  with a gravel pack system; 
       FIG. 26  is an embodiment of a control line system, for use in a plurality of use in wellbore zones; 
       FIG. 27  is a view similar to  FIG. 6  with a single dip tube; 
       FIG. 28  is another embodiment of the control line system illustrated in  FIG. 20 ; 
       FIG. 29  is a view similar to  FIG. 28  with an embodiment of a dip tube mounted on a removable plug; 
       FIG. 30  is another embodiment of the control line system illustrated in  FIG. 20 ; 
       FIG. 31  is a view similar to  FIG. 30  in which an embodiment of a dip tube is mounted on a removable plug; 
       FIG. 32  illustrates another embodiment of the control line system illustrated in  FIG. 20 ; 
       FIG. 33  is an isometric view of a dip tube pivot joint; 
       FIG. 34  illustrates an embodiment of a dip tube mounted on a fishable plug; 
       FIG. 35  is a view similar to  FIG. 34  with a mechanism to accommodate full bore flow; 
       FIG. 36  is a view similar to  FIG. 34  illustrating an embodiment of a hydraulic wet connect. 
       FIG. 37  is a perspective view of an embodiment of a fiber optic engagement system; 
       FIG. 38  is an expanded view of an embodiment of a course alignment system illustrated in FIG.  37 ;and 
       FIG. 39  illustrates an embodiment of fiber optic connectors for use with a system, such as the system illustrated in  FIG. 37 . 
   

   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. 
   DETAILED DESCRIPTION OF THE INVENTION 
   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,  FIG. 1  illustrates a wellbore  10  that has penetrated a subterranean zone  12  that includes a productive formation  14 . The wellbore  10  has a casing  16  that has been cemented in place. The casing  16  has a plurality of perforations  18  which allow fluid communication between the wellbore  10  and the productive formation  14 . A well tool  20 , such as a sand control completion, is positioned within the casing  16  in a position adjacent to the productive formation  14 , which is to be gravel packed. 
   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.  FIG. 1  shows an optional lower packer  30  located below the perforations  18 . 
   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,  FIG. 2  illustrates one particular application of the present invention in which two lateral wellbores are completed, an upper lateral  48  and a lower lateral  50 . Both lateral wellbores are completed with a gravel pack operation comprising a lateral isolation packer  46  and a sand screen assembly  28 . 
   Similarly,  FIG. 3  shows another exemplary embodiment in which two laterals are completed with a sand control completion and a gravel pack operation. The lower lateral  50  in  FIG. 3  has multiple zones isolated from one another by a packer  42 . 
   In each of the examples shown in  FIGS. 1 through 3 , a control line  60  extends into the well and is provided adjacent to the screen  28 . Although shown with the control line  60  outside the screen  28 , other arrangements are possible as disclosed herein. Note that other embodiments discussed herein will also comprise intelligent completions devices  62  in the gravel pack, the screen  28 , or the sand control completion. 
   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, H 2 S detectors, CO 2  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. 
     FIG. 4  is a cross sectional view of one embodiment of a screen  28  of the present invention. The sand screen  28  generally comprises a base pipe  70  surrounded by a filter media  72 . To provide for the flow of fluid into the base pipe  70 , it has perforations therethrough. The screen  28  is typical to those used in wells such as those formed of a screen wrap or mesh designed to control the flow of sand therethrough. Surrounding at least a portion of the base pipe  70  and filter media  72  is a perforated shroud  74 . The shroud  74  is attached to the base pipe  70  by, for example, a connecting ring or other connecting member extending therebetween and connected by a known method such as welding. The shroud  74  and the filter media  72  define a space therebetween  76 . 
   In the embodiment shown in  FIG. 4 , the sand screen  28  comprises a plurality of shunt tubes  78  (also known as alternate paths) positioned in the space  76  between the screen  28  and the shroud  74 . The shunt tubes  78  are shown attached to the base pipe  70  by an attachment ring  80 . The methods and devices of attaching the shunt tubes  78  to the base pipe  70  may be replaced by any one of numerous equivalent alternatives, only some of which are disclosed in the specification. The shunt tubes  78  can be used to transport gravel laden slurry during a gravel pack operation, thus reducing the likelihood of gravel bridging and providing improved gravel coverage across the zone to be gravel packed. The shunt tubes  78  can also be used to distribute treating fluids more evenly throughout the producing zone, such as during an acid stimulation treatment. 
   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. 
     FIG. 4  also shows other alternative embodiments for routing of control lines  60  and for placement of intelligent completions devices  62  such as sensors therein. As shown in previous figures, the control line  60  may extend outside of the sand screen  28 . In one alternative embodiment, a control line  60   a  extends through one or more of the shunt tubes  78 . In another embodiment, the control line  60   b  is placed between the filter media  72  and the shroud  74  in the space  76 .  FIG. 4  shows another embodiment in which a sensor  62   a  is placed in a shunt tube  78  as well as a sensor  62   b  attached to the shroud  74 . Note that an array of such sensors  62   a  may be placed along the length of the sand screen  28 . In another alternative embodiment, the base pipe  70  may have a passageway  84 , or groove, therein through which a control line  60   c  may extend and in which an intelligent completions device  62   c  may be placed. The passageway  84  may be placed internally in the base pipe  70 , on an inner surface of the base pipe  70 , or on an outer surface of the base pipe  70  as shown in  FIG. 4 . 
   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.  FIG. 5  illustrates a screen  28  having a control line  60  that is routed in a helical path along the screen  28 . In one embodiment, the control line  60  comprises a fiber optic line that is helically wound about the screen  28  (internal or external to the screen  28 ) to increase resolution at the screen. In this embodiment, a fiber optic line comprises a distributed temperature system. Other paths about the screen  28  that increase the length of the fiber optic line per longitudinal unit of length of screen  28  will also serve to increase the resolution of the functionality provided by the fiber optic line. 
     FIGS. 6 and 7  illustrate a number of alternative embodiments for placement of control lines  60  and intelligent completions device  62 .  FIG. 6  shows a sand screen  28  that has a shroud  74 , whereas the embodiment of  FIG. 7  does not have a shroud  74 . 
   In both  FIGS. 6 and 7 , the control line  60  may be routed along the base pipe  70  via an internal passageway  84   a , a passageway  84   b  formed on an internal surface of the base pipe  70 , or a passageway  84   c  formed on an external surface of the base pipe  70 . In one alternative embodiment, the base pipe  70  (or a portion thereof) is formed of a composite material. In other embodiments, the base pipe  70  is formed of a metal material. Similarly, the control line  60  may be routed along the filter media  72  through an internal passageway  84   d , a passageway  84   e  formed on an internal surface of the filter media  72 , or a passageway  84   f  formed on an external surface of the filter media  72 . Likewise, the control line  60  may be routed along the shroud  74  through an internal passageway  84   g , a passageway  84   h  formed on an internal surface of the shroud  74 , or a passageway  84   i  formed on an external surface of the shroud  74 . The shroud  74  may be formed of a metal or composite material. In addition, the control line  60  may also extend between the base pipe  70  and the filter media  72 , between the filter media  72  and the shroud  74 , or outside the shroud  74 . In one alternative embodiment, the filter media has an impermeable portion  86 , through which flow is substantially prevented, and the control line  60  is mounted in that portion  86 . Additionally, the control line  60  may be routed through the shunt tubes  78  or along the side of the shunt tubes  78  ( 60   d  in  FIG. 4 ). Combinations of these control line  60  routes may also be used (e.g., a particular device may have control lines  60  extending through a passageway formed in the base pipe  70  and through a passageway formed in the shroud  74 ). Each position has certain advantages and may be used depending upon the specific application. 
   Likewise,  FIGS. 6 and 7  show a number of alternatives for positioning of an intelligent completions device  62  (e.g., a sensor). In short, the intelligent completions device  62  may be placed within the walls of the various components (e.g., the base pipe  70 , the filter media  72 , the shroud  74  and, the shunt tube  78 ), on an inner surface or outer surface of the components ( 70 ,  72 ,  74 ,  78 ), or between the components ( 70 ,  72 ,  74 ,  78 ). Also, the components may have recesses  89  formed therein to house the intelligent completions device  62 . Each position has certain advantages and may be used depending upon the specific application. 
   In the alternative embodiment of  FIG. 8 , the control line  60  is placed in a recess in one of the components ( 70 ,  72 ,  74 ,  78 ). A material filler  88  is placed in the recess to mold the control line in place. As an example, the material filler  88  may be an epoxy, a gel that sets up, or other similar material. In one embodiment, the control line  60  is a fiber optic line that is molded to, or bonded to, a component ( 70 ,  72 ,  74 ,  78 ) of the screen  28 . In this way, the stress and/or strain applied to the screen  28  may be detected and measured by the fiber optic line. Further, the fiber optic line may provide seismic measurements when molded to the screen  28  (or other downhole component or equipment) in this way. 
   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  FIG. 9 , a well  10  has a casing  16  extending to an open-hole portion. At the upper end of the expandable tubing  90  is a hanger  92  connecting the expandable tubing  90  to a lower end of the casing  16 . A crossover section  94  connects the expandable tubing  90  to the hanger  92 . However, other known methods of connecting an expandable tubing  90  to a casing  16  may be used, or the expandable tubing  90  may remain disconnected from the casing  16 .  FIG. 9  is but one illustrative embodiment. In one embodiment, the expandable tubing  90  (connected to the crossover section  94 ) is connected to another expandable tubing  90  by an unexpanded, or solid, tubing  96 . The unexpanded tubing is provided for purposes of illustration only and other completions may omit the unexpanded tubing  96 . A control line  60  extends from the surface and through the expandable tubing completion.  FIG. 9  shows the control line  60  on the outside of the expandable tubing  90  although it could run through the wall of the expandable tubing  90  or internal to the expandable tubing  90 . In one embodiment, the control line  60  is a fiber optic line that is bonded to the expandable tubing  90  and used to monitor the expansion of the expandable tubing  90 . For example, the fiber optic line could measure the temperature, the stress, and/or the strain applied to the expandable tubing  90  during expansion. Such a system would also apply to a multilateral junction that is expanded. If it is determined, for example, that the expansion of the expandable tubing  90  or a portion thereof is insufficient (e.g., not fully expanded), a remedial action may be taken. For example, the portion that is not fully expanded may be further expanded in a subsequent expansion attempt, also referred to as reexpanded. 
   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 . 
     FIG. 10  illustrates an alternative embodiment of the present invention in which a plurality of expandable tubings  90  are separated by unexpanded tubing sections  96 . As in the embodiment of  FIG. 9 , the expandable tubing  90  is connected to the casing  16  of the well  10  by a hanger  92  (which may be a packer). The expandable tubing sections  90  are aligned with separate perforated zones and expanded. Each of the unexpanded tubing sections  96  has an external casing packer  98  (also referred to generally herein as a “seal”) thereon that provides zonal isolation between the expandable tubing sections  90  and associated zones. Note that the external casing packer  98  may be replaced by other seals  28  such as an inflate packer, a formation packer, and or a special elastomer or resin. A special elastomer or resin refers to an elastomer or resin that undergoes a change when exposed to the wellbore environment or some other chemical to cause the device to seal. For example, the elastomer may absorb oil to increase in size or react with some injected chemical to form a seal with the formation. The elastomer or resin may react to heat, water, or any method of chemical intervention. 
   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  FIG. 10 , the zonal isolation is completed by an inner completion inserted into the expandable completion. The inner completion comprises a production tubing  100  extending into the expandable completion. Packers  42  positioned between each of the zones to isolate the production of each zone and allow separate control and monitoring. It should be noted that the packers  42  may be replaced by seal bores and seal assemblies or other devices capable of creating zonal isolation between the zones (all of which are also referred to generally herein as a “seal”). In the embodiment shown, a valve  102  in the inner completion provides for control of fluid flow from the associated formation into the production tubing  100 . The valve  102  may be controlled from the surface or a downhole controller by a control line  60 . 
   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 ,  FIG. 11  illustrates a screen  28  that has an expandable base pipe  104 , an expandable shroud  106 , and a series of scaled filter sheets  108  therebetween providing the filter media  104 . Some of the filter sheets are connected to a protective member  110  which is connected to the expandable base pipe  104 . The figure shows, for illustration purposes, a number of control lines  60  and an intelligent completions device  62  attached to the screen  28 . 
     FIG. 12  illustrates another embodiment of the present invention in which an expandable tubing  90  has a relatively wider unexpanding portion (e.g., a relatively wider thick strut in a bistable cell). One or more grooves  112  extend the length of the expandable tubing  90 . A control line  60  or intelligent completions device  62  may be placed in the groove  112  or other area of the expandable tubing. Additionally, the expandable tubing  90  may form a longitudinal passageway  114  therethrough that may comprise or in which a control line  60  or intelligent completions device  62  may be placed. 
   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  FIGS. 13 and 14 . The connector  120  has a set of internal ratchet teeth  122  that mate with external ratchet teeth  124  formed on the components to be connected. For example, adjacent screens  28  may be connected using the connector  120 . Seals  126  between the connector  120  and components provide a sealed system. The connector  120  has passageways  128  extending therethrough that may be readily aligned with passageways in the connected equipment. Although shown as a separate connector  120 , the ratchets may be formed on the ends of the components themselves to achieve the same resultant non-rotating connection. 
   Another type of non-rotating connection is a snap fit connection  130 . As best seen in  FIG. 15 , the pin end  132  of the first component  134  has a reduced diameter portion at its upper end, and an annular exterior groove  136  is formed in the reduced diameter portion above an O-ring sealing member externally carried thereon. A split locking ring member  138 , having a ramped and grooved outer side surface profile as indicated, is captively retained in the groove  136  and lockingly snaps into a complementarily configured interior side surface groove  140  in the box end  142  of the second component  135  when the pin end  132  is axially inserted into the box end  142  with the passageway  128  of the pin end  132  in circumferential alignment that of the box end  142 . Although shown as formed on the ends of the components themselves the snap fit connectors  130  may be employed in an intermediate connector  120  to achieve the same resultant non-rotating connection. 
   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  FIG. 16 ), a hydraulic wet connect  144  is made downhole to place a lower passageway  146  into fluid communication with an upper passageway  148 . A seal  150  between the upper and lower components provides a sealed passageway system. The fiber optic line  60  is subsequently deployed into the completed passageway. 
   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  FIGS. 17A and 17B , a service string  160  is shown disposed within the production tubing  162  and connected to a service tool  164 . The service string  160  may be any type of string known to those of skill in the art, including but not limited to jointed tubing, coiled tubing, etc. Likewise, although shown as a thru-tubing service tool, the present invention may employ any type of service tool and service string. For example, the service tool  164  may be of the type that is manipulated by movement of the service tool  164  relative to the upper packer  166 . A gravel pack operation is performed by manipulating the service tool  164  to provide for the various pumping positions/operations (e.g., circulating position, squeeze position, and reversing position) and pumping the gravel slurry. 
   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 .  FIG. 17C  illustrates an exemplary cross section of the service tool  164  showing a control line  60  provided in a passageway of a wall thereof. The figure also shows an alternative embodiment in which the service tool  164  has a sensor  62  therein. Note that the control line  60  or sensor  62  may be placed in other positions within 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. 
     FIGS. 18A–D  disclose yet another embodiment of the present invention comprising a service tool  164  that provides a fiber optic line therein. In the embodiment illustrated, the fiber optic line  60  is run along a washpipe  170  and to a position above a setting tool  172  to a special wet connect sub  174 . This sub  174  allows for a “slick-line” conveyed (or otherwise conveyed) plug  176  to be set therein. The “slick-line” encapsulates a fiber optic line. This can use a control line or other line (e.g., tubing encapsulated line or line in a coiled tubing) or sensor, or it can be a wound wire or wireline with fiber optic encased therein. 
   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  FIG. 18A , the washpipe  170  has a control line  60  mounted, either temporarily or permanently along the outside of the washpipe or mounted in some other manner that allows the fiber optic line in the control line to be exposed to the temperatures both internal of and external of the washpipe as desired. In this example, the washpipe is connected to the sand control service tool  164  with an integral fiber optic conduit. A fiber optic crossover tool (FOCT)  178  and the attached setting tool  172  have a fiber optic line routed therethrough. The wet connect sub is attached to the assembly above the setting tool  172 . 
   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  FIGS. 19A and 19B , another embodiment of a wet connect system is illustrated. The wet connect system facilitates the connection of a control line or control lines, e.g., control line  60 . The system provides a wet connect tool  180  that may be run on a production string  182  for interfacing with a mating connect component  184  placed below a packer  186 . The mating connect component  184  is, for example, part of a liner  188  that may have various control lines coupled to liner components below the packer  186 . 
   After placing liner  188  in the wellbore, the wet connect tool  180  is run into the well, as illustrated in  FIG. 19A . As the “run in” is continued, wet connect tool  180  is moved through packer  186  and into engagement with mating connect component  184 . By way of example, wet connect tool  180  may comprise a spring loaded dog  190  that is biased into a corresponding receptacle  192  when the wet connect is completed, as illustrated in  FIG. 19B . As production string  182  is landed, the fiber optic lines may be positioned using a passageway or passageways  193 , e.g. gun drilled ports, through a seal assembly  194 , as illustrated in  FIG. 19B . Seal assembly  194  seals in the packer bore of packer  186 . The fiber optic line or other control line  60  passes through passageway  193 . As described above, multiple control lines can be used, and multiple passageways  193  may be formed longitudinally through seal assembly  194 . The control line, e.g. control line  60 , may comprise hydraulic control lines for actuation of components or delivery of wellbore chemicals, fiber optic lines, electrical control lines or other types of internal control lines depending on the particular application. 
   In an alternate embodiment, as illustrated in  FIG. 19C , the gun drilled seal assembly is replaced with a multiport packer  195  used for sealing and anchoring. Multiport packer  195  is disposed above packer  186 , which may be a gravel pack packer. In this system, a fluted locator  196  may be used within the packer bore without a seal. However, the fluted locator extends downwardly via, for example, a tube  197  for connection to other components. 
   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  FIG. 20 , a well system  200  comprises a control line system  201  and is illustrated according to an embodiment of the present invention. System  200  is deployed within a wellbore and comprises a lower completion  202 , an upper completion  204  and a stinger or a dip tube  206 . 
   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  FIG. 21 , the upper completion  204  comprises a plurality of side pocket subs  214  arranged in a stacked configuration. At least one dip tube  206  is connected to connection feature  216  via a corresponding connection feature, e.g. a wet connect mandrel  224 . The connection features  216  may be located at different angular positions to accommodate insertion of dip tubes  206  through upper packer  212  and lower packer  208 . 
   Another embodiment of system  200  is illustrated in  FIG. 22 . In this embodiment, side pocket sub  214  comprises an upper connection feature  234  to which dip tube  206  is coupled in a “lock-up” position rather than a “lock-down” position, as in the embodiments illustrated in  FIGS. 20 and 21 . In other words, a connection, such as a wet connect, is formed by moving a corresponding connecting feature  236  of dip tube  206  upwardly into engagement with upper connection feature  234  of side pocket sub  214 . As described with previous embodiments, the connection may be a wet connect in which corresponding connection feature  236  is formed on a wet connect mandrel  238  sized to fit within the side pocket  240  of side pocket sub  214 . As previously discussed, control line  230  may comprise a variety of control lines, but one example is a fiber optic control line that forms a fiber optic wet connect across upper connection  234  and corresponding connection feature  236 . 
   Referring generally to  FIG. 23 , another embodiment of system  200  is illustrated. In this embodiment, the lower completion  202  having, for example, packer  208 , formation isolation valve  210  and screen  211  is coupled to upper completion  204  by an expansion joint  242 . In the example illustrated, expansion joint  242  comprises a telescopic joint that compensates for deviation in the gap or distance between lower completion  202  and upper completion  204 . Also, upper completion  204  may have a tubing isolation valve  243  to, for example, facilitate setting of packer  212 . 
   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  FIG. 24 . In this embodiment, an entire completion  258  comprising lower completion  202  and upper completion  204  can be run in hole in a single trip. Accordingly, it is not necessary to form wet connects along control line  230 . Although completion  238  may comprise a variety of embodiments, in the embodiment illustrated, packer  212  and packer  208  are mounted on tubing  218 . Between packer  208  and  212 , a valve  260 , such as a ball valve, is mounted. Additionally, a circulating valve  262  may be mounted above valve  260 . Below packer  208 , screen  211  comprises an expandable screen section  264  along which or through which control line  230  extends. 
   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  FIG. 24  as expanded screen  264 . 
   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  FIG. 24  is illustrated in  FIG. 25 . In this embodiment, the expandable sand screen is replaced with a gravel pack system  270 . By way of example, gravel pack system  270  may comprise a gravel pack port closure sleeve  272  and a base pipe sand screen  274 . The control line  230  may be deployed externally of the base pipe sand screen  274 . In operation, the same single trip procedure as discussed with respect to  FIG. 24  may be utilized. However, instead of performing the act of expanding the sand screen, a gravel pack is run. It also should be noted that. the systems illustrated generally in  FIGS. 24 and 25  can be utilized with multi-zoned intelligent completions. 
   Another embodiment of system  200  is illustrated in  FIG. 26 . In this embodiment, a multiple completion  276  is illustrated for use in at least two wellbore zones  278 ,  280 . Wellbore zone  280  is isolated by a packer  282  to which an expandable sand screen  284  is connected. A tubing  286  extends through packer  282  and into communication with expandable sand screen  284 . Tubing  286  may utilize a polished bore receptable  287  above packer  282  to facilitate construction of multiple completion  276 . Additionally, a formation isolation valve  288  may be deployed between packer  282  and sand screen  284 . 
   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  FIGS. 20–23 . For example, a control line  304  associated with dip tube  300  may be connected though a wet connect/snap latch mechanism  306  disposed above a packer  308  located up hole from packer  294 . As described with reference to  FIG. 23 , an expansion joint  310  may be utilized to facilitate the connection of wet connect and snap latch  306  when an upper completion is moved into location within the wellbore above packer  308 . Furthermore, dip tube  302  and its associated control line  312  may be moved through the center of tubing  286  and into connection with the upper portion of control line  312  via a wet connect  314  disposed in a side pocket sub  316 . It should be noted that in at least some applications, a plug  318  may be utilized in cooperation with side pocket sub  316  to selectively block flow through tubing  286  while the tubing is pressurized to set upper packer  320  disposed above side pocket sub  316 . Accordingly, by sequentially moving completion sections to appropriate wellbore locations, a multiple completion can be constructed with separate control lines isolated in separate wellbore zones. Also, individual dip tubes in combination with, for example, a fiber optic line may be used to sense parameters from more than one zone. Center dip tube  302  and an inner fiber optic line can be used to measure temperature in zones  278  and  280  without direct contact with fluid from both zones. 
   In  FIG. 27 , for example, another embodiment of multiple completion  276  is illustrated. In this embodiment, fluid is produced from multiple wellbore zones, e.g. wellbore zone  278  and wellbore zone  280 , but the outlying dip tube  300  has been eliminated. Accordingly, expansion joint  310  also is no longer necessary in this particular application. As illustrated, the single dip tube  302  extends through tubing  286  into the interior of expandable sand screen  284 . As with previous embodiments, the dip tube  302  can be utilized for a variety of applications, including chemical injection, sensing and other control line related functions. For example, dip tube  302  may be perforated to expose an internal fiber optic distributed temperature sensor. 
   Another embodiment of a system  200  is illustrated in  FIG. 28 . In this embodiment, the control line  230  is combined with an embodiment of upper completion  204  that may be deployed in a single trip. By way of example, lower completion  202  comprises a packer  322 , such as a screen hangar packer, and sand screen  324 , such as an expandable sand screen, suspended from packer  322 . Additionally, a latch member  326  may be deployed above packer  322  to receive upper completion  204 . 
   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  FIG. 29 , a similar design to that of  FIG. 28  is illustrated but with a removable stinger/dip tube  342 . In this embodiment, the dip tube  342  is coupled to a retrievable plug  344 . The control line or lines  230  are routed through plug  344  and into or along dip tube  342 . However, the retrievable plug allows the dip tube  342  to be retrieved through tubing  340  without pulling upper completion  204 . In the embodiment illustrated, there is no wet connect between retrievable plug  344  and the remainder of upper completion  204 . Accordingly, if plug  344  and dip tube  342  are retrieved, the control line  230  is cut or otherwise severed. 
   Referring generally to  FIG. 30 , another configuration of control line system  200  is illustrated. In this embodiment, a sand screen such as an expandable sand screen  346 , along with a screen hangar packer  348  are initially run into the wellbore. Subsequently, an anchor packer  350  along with a formation isolation valve  352 , a wet connect member  354  and a lower section  356  of control line  230  are run in hole and positioned within the wellbore. In this embodiment, a dip tube  358  is provided to receive at least a portion of control line lower section  356 , and dip tube  358  is positioned to extend through screen hangar packer  348  into expandable sand screen  346 . 
   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  FIG. 31 . However, in this embodiment, dip tube  358  is coupled to a removable plug  372 . As described above with reference to  FIG. 29 , removable plug  372  enables the removal of dip tube  358  through tubing  360  without removal of the completion or segments of the completion. 
   Referring generally to  FIG. 32 , another embodiment of system  200  is illustrated. In this embodiment, one example of a lower completion  374  comprises a screen  376 , such as a base pipe screen, a formation isolation valve  378 , a port closure sleeve  380  and a packer  382 . However, a variety of other components can be added or interchanged in the construction of lower completion  374 . A space out gap is disposed between lower completion  374  and an upper completion  386 . By way of example, upper completion  386  comprises an upper packer  388  mounted to tubing  390 . A tubing isolation valve  392  is disposed below packer  388  in cooperation with tubing  390 . A slotted pup  394  is disposed below tubing isolation valve  392  to permit inwardly directed fluid flow from an outer fluid flow path  396 . The outer fluid flow path  396  flows around a control line side step plug  398  to which a dip tube  400  is mounted at an offset location to permit a generally centralized fluid flow along a fluid flow path  402 . Thus, fluid may flow to tubing  390  via outer or inner flow paths. The side step plug  398  may be designed to receive fiber optic lines or other types of control lines therethrough. The control line can be connected through a wet connect  404  proximate side step plug  398 , or a dry connect may be utilized. 
   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  FIG. 33 . In this example, a dip tube  406  which may embody many of the dip tubes described above, is coupled to a subject system by a pivot joint  408 . By way of example, pivot joint  408  may be constructed by forming a ball  410  at the base of dip tube  406 . The ball  410  is sized for receipt in a corresponding receptacle  412  for pivotable movement. The pivot joint  408  enables movement of dip tube  406  as it is run into a given wellbore. The ability to pivot can facilitate movement past obstructions or into deviated wellbores. In deviated wells, the control line also can be strapped externally to a perforated pipe, or friction reducing members, e.g., rollers, can be coupled to the dip tube. 
   Referring generally to  FIGS. 34 through 36 , alternate dip tube embodiments are illustrated. In each of these embodiments, a dip tube  414  is deployed at a desired wellbore location. As illustrated in  FIG. 34 , dip tube  414  and a connector  416  are mounted to a retrievable plug  418  having a fishing feature  420 . Fishing feature  420  may be an internal or external feature configured for engagement with a fishing tool (not shown) to permit retrieval and potentially insertion of dip tube  414  through production tubing  422 . 
   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  FIG. 35 , a base  436  of mounting mechanism  430  may be formed as a removable component. For example, the base  436  may be coupled to a side wall  438  of mounting mechanism  430  by a sheer pin or other coupling mechanism  440 . Thus, the base  436  can be released or broken free from the remainder mounting mechanism  430  to provide a substantially uninhibited axial flow from tubing  426  through mounting mechanism  430  and into tubing  422 . By way of example, the fishable dip tube  414  can be retrieved from the completion, and base  436  may be knocked down hole to provide a full bore flow. 
   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  FIG. 36 , the hydraulic wet connection feature  442  pivots outwardly for engagement with an upper section  446  of control line  230 . As described above, the control line  230  may comprise a variety of control lines including tubes, wire, fiber optics and other control lines through which various materials or signals flow. It should also be noted that a variety of other types of connectors can be utilized with the various control line systems illustrated. 
   Referring generally to  FIGS. 37 through 39 , a system  450  for connecting a fiber optic line in a wellbore is illustrated. By way of example, system  450  may comprise a lower completion  452 , an upper completion  454  and an alignment system  456 . In the embodiment illustrated, lower completion  452  comprises a receptacle assembly  458  having a polished bore receptacle  460 , an open receiving end  462  and a receptacle latch  464  generally opposite open receiving end  462 . 
   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  FIG. 38 ) is actuated to rotationally release stinger  466  with respect to fiber optic cable accumulator  470 . Thus, alignment system  456  can rotate stinger  466  to properly align the fiber optic cable segments in lower completion  452  and upper completion  454 , enabling a downhole wet connect. 
   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  FIG. 39 . As illustrated, at least one and often a plurality of fiber optic cable segments  482  extend longitudinally along or through upper completion  454  and terminate at wet plugable connector ends  484 . Similarly, fiber optic cable segments  486  extend along or through lower completion  452  to corresponding fiber optic connector ends  488 . In this embodiment, a plurality of fine tuning keys  490  are connected to the interior of receptacle assembly  458 , as shown schematically in  FIG. 39 . The fine tuning keys  490  have tapered lead ends  492  that are slidably received in corresponding grooves  494  formed in the exterior of stinger  466 . As tapered ends  492  move into grooves  494 , the fine tuning keys  490  are able to rotationally adjust stinger  466  for precise plugable connection of connector ends  484  with corresponding connector ends  488  to establish a wet connect between one or more fiber optic cables. It should be noted that the upper and lower completions can utilize a variety of other components, and the arrangement of alignment keys, helical cuts, internal grooves and other features can be interchanged between the upper completion and the lower completion. 
   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.