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CROSS-REFERENCE TO RELATED APPLICATIONS 
     This is a continuation-in-part of application Ser. No. 12/372,862, filed Feb. 18, 2009, now U.S. Pat. No. 8,122,967, issued Feb. 28, 2012. 
    
    
     TECHNICAL FIELD OF THE INVENTION 
     This invention relates, in general, to equipment utilized and operations performed in conjunction with a subterranean well and, in particular, to an apparatus and method for controlling the connection and disconnection speed of downhole connectors. 
     BACKGROUND OF THE INVENTION 
     Without limiting the scope of the present invention, its background is described with reference to using optical fibers for communication and sensing in a subterranean wellbore environment, as an example. 
     It is well known in the subterranean well completion and production arts that downhole sensors can be used to monitor a variety of parameters in the wellbore environment. For example, during a treatment operation, it may be desirable to monitor a variety of properties of the treatment fluid such as viscosity, temperature, pressure, velocity, specific gravity, conductivity, fluid composition and the like. Transmission of this information to the surface in real-time or near real-time allows the operators to modify or optimize such treatment operations to improve the completion process. One way to transmit this information to the surface is through the use of an energy conductor which may take the form of one or more optical fibers. 
     In addition or as an alternative to operating as an energy conductor, an optical fiber may serve as a sensor. It has been found that an optical fiber may be used to obtain distributed measurements representing a parameter along the entire length of the fiber. Specifically, optical fibers have been used for distributed downhole temperature sensing, which provides a more complete temperature profile as compared to discrete temperature sensors. In operation, once an optical fiber is installed in the well, a pulse of laser light is sent along the fiber. As the light travels down the fiber, portions of the light are backscattered to the surface due to the optical properties of the fiber. The backscattered light has a slightly shifted frequency such that it provides information that is used to determine the temperature at the point in the fiber where the backscatter originated. In addition, as the speed of light is constant, the distance from the surface to the point where the backscatter originated can also be determined. In this manner, continuous monitoring of the backscattered light will provide temperature profile information for the entire length of the fiber. 
     Use of an optical fiber for distributed downhole temperature sensing may be highly beneficial during the completion process. For example, in a stimulation operation, a temperature profile may be obtained to determine where the injected fluid entered formations or zones intersected by the wellbore. This information is useful in evaluating the effectiveness of the stimulation operation and in planning future stimulation operations. Likewise, use of an optical fiber for distributed downhole temperature sensing may be highly beneficial during production operations. For example, during a production operation a distributed temperature profile may be used in determining the location of water or gas influx along the sand control screens. In a typical completion operation, a lower portion of the completion string including various tools such as sand control screens, fluid flow control devices, wellbore isolation devices and the like is permanently installed in the wellbore. The lower portion of the completion string may also include various sensors, such as a lower portion of the optical fiber. After the completion process is finished, an upper portion of the completions string which includes the upper portion of the optical fiber is separated from the lower portion of the completion string and retrieved to the surface. This operation cuts off communication between the lower portion of the optical fiber and the surface. Accordingly, if information from the production zones is to be transmitted to the surface during production operations, a connection to the lower portion of the optical fiber must be reestablished when the production tubing string is installed. 
     It has been found, however, that wet mating optical fibers in a downhole environment is very difficult. This difficulty is due in part to the lack of precision in the axially movement of the production tubing string relative to the previously installed completion string. Specifically, the production tubing string is installed in the wellbore by lowering the block at the surface, which is thousands of feet away from the downhole landing location. In addition, neither the distance the block is moved nor the speed at which the block is moved at the surface directly translates to the movement characteristics at the downhole end of the production tubing string due to static and dynamic frictional forces, gravitational forces, fluid pressure forces and the like. The lack of correlation between block movement and the movement of the lower end of the production tubing string is particularly acute in slanted, deviated and horizontal wells. This lack in precision in both the distance and the speed at which the lower end of the production tubing string moves has limited the ability to wet mate optical fibers downhole as the wet mating process requires relatively high precision to sufficiently align the fibers to achieve the required optical transmissivity at the location of the connection. 
     Therefore, a need has arisen for an apparatus and method for wet connecting optical fibers in a subterranean wellbore environment. A need has also arisen for such an apparatus and method for wet connecting optical fibers that is operable to overcome the lack of precision in the axial movement of downhole pipe strings relative to one another. Further, a need has arisen for such an apparatus and method for wet connecting optical fibers that is operable to overcome the lack of precision in the speed of movement of downhole pipe strings relative to one another. 
     SUMMARY OF THE INVENTION 
     The present invention disclosed herein is directed to an apparatus and method for wet connecting downhole communication media in a subterranean wellbore environment. The apparatus and method of the present invention are operable to overcome the lack of precision in the axial movement of downhole pipe strings relative to one another. In addition, the apparatus and method of the present invention are operable to overcome the lack of precision in the speed of movement of downhole pipe strings relative to one another. In carrying out the principles of the present invention, a wet connection apparatus and method are provided that are operable to control the connection speed of downhole connectors. 
     In one aspect, the present invention is directed to a method for controlling the connection speed of downhole connectors in a subterranean well. The method includes positioning a first assembly having a first downhole connector and a first communication medium in the well; engaging the first assembly with a second assembly, the second assembly including a second downhole connector and a second communication medium, the second assembly having an outer portion and an inner portion that are initially coupling together with a lock assembly; unlocking the outer portion of the second assembly from the inner portion of the second assembly by radially shifting at least one lug; axially shifting the outer portion of the second assembly relative to the inner portion of the second assembly; and operatively connecting the first and second downhole connectors, thereby enabling communication between the first and second communication media. 
     The method may also include, radially shifting a plurality of lugs of the lock assembly to unlock the outer portion of the second assembly from the inner portion of the second assembly; longitudinally shifting a plunger of the lock assembly responsive to contact with the first assembly to radially retract the at least one lug; radially retracting the at least one lug responsive to contact between at least one lug extension of the lock assembly and the first assembly; controlling an axial shifting speed of the outer portion of the second assembly relative to the inner portion of the second assembly with a resistance assembly by, for example, metering a fluid through a transfer piston; anchoring the second assembly within the first assembly by propping a key assembly of the second assembly within a profile of the first assembly; overcoming a biasing force of a spring operably associated with the transfer piston to control the axially shifting speed of the outer portion of the second assembly relative to the inner portion of the second assembly; resisting disconnection of the first and second downhole connectors by locking the outer portion of the second assembly with the inner portion of the second assembly by, for example, engaging a collet assembly of the outer portion of the second assembly with a shoulder of the inner portion of the second assembly by continuing the axial shifting of the outer portion of the second assembly relative to the inner portion of the second assembly after connecting the first and second downhole connectors; and/or selecting the communication media from the group consisting of optical fibers, electrical conductors and hydraulic fluid. 
     In another aspect, the present invention is directed to an apparatus for controlling the connection speed of downhole connectors in a subterranean well. The apparatus includes a first assembly having a first downhole connector and a first communication medium that is positionable in the well. A second assembly includes a second downhole connector and a second communication medium and has an outer portion and an inner portion that are selectively axially shiftable relative to one another. A lock assembly including at least one lug initially couples the outer and inner portions of the second assembly together such that, upon engagement of the first assembly with the second assembly, the at least one lug is radially shifted releasing the lock assembly to allow axial shifting of the outer portion of the second assembly relative to the inner portion of the second assembly, thereby operatively connecting the first and second downhole connectors to enable communication between the communication media. 
     In one embodiment, the lock assembly includes a plurality of lugs. In another embodiment, the lock assembly includes a plunger assembly that longitudinally shifts relative to the at least one lug responsive to contact with the first assembly to radially retract the at least one lug. In a further embodiment, the lock assembly includes at least one lug extension that radially retracts the at least one lug responsive to contact between the at least one lug extension and the first assembly. In certain embodiments, a resistance assembly is positioned between the outer portion of the second assembly and the inner portion of the second assembly that controls the axial shifting speed of the outer and inner portions of the second assembly relative to one another. In such embodiments, the resistance assembly may include a transfer piston operable to have fluid metered therethrough and a spring operably associated with the transfer piston. In one embodiment, the second assembly includes a key assembly and the first assembly includes a profile such that the key assembly may be propped within the profile to anchor the second assembly within the first assembly. In another embodiment, the inner portion of the second assembly may include a shoulder and the outer portion of the second assembly may include a collet assembly. In this embodiment, continued axial shifting of the outer portion of the second assembly relative to the inner portion of the second assembly after connecting the first and second downhole connectors engages the collet assembly with the shoulder to selectively lock the outer portion of the second assembly with the inner portion of the second assembly to resist disconnection of the first and second downhole connectors. In certain embodiments, the communication media are selected from the group consisting of optical fibers, electrical conductors and hydraulic fluid conductor. 
     In a further aspect, the present invention is directed to a method for controlling the connection speed of downhole connectors in a subterranean well. The method includes positioning a first assembly having a first downhole connector and a first communication medium in the well; engaging the first assembly with a second assembly having a second downhole connector and a second communication medium; unlocking an outer portion of the second assembly from an inner portion of the second assembly by radially shifting at least one lug; axially shifting the outer portion of the second assembly relative to the inner portion of the second assembly while metering a fluid through a transfer piston to control the axially shifting speed thereof; and operatively connecting the first and second downhole connectors, thereby enabling communication between the first and second communication media. 
     In yet another aspect, the present invention is directed to an apparatus for controlling the connection speed of downhole connectors in a subterranean well. The apparatus includes a first assembly having a first downhole connector and a first communication medium that is positionable in the well. A second assembly includes a second downhole connector and a second communication medium. The second assembly has an outer portion and an inner portion with a transfer piston positioned therebetween. The outer portion is selectively axially shiftable relative to the inner portion. A lock assembly including at least one lug initially couples the outer and inner portions of the second assembly together such that, upon engagement of the first assembly with the second assembly, the at least one lug is radially shifted to release the lock assembly and allow axial shifting of the outer portion of the second assembly relative to the inner portion of the second assembly while a fluid is metered through the transfer piston to control the speed at which the outer and inner portions of the second assembly axially shift relative to one another such that the first and second downhole connectors are operatively connected at a predetermined connection speed, thereby enabling communication between the communication media. 
     In an additional aspect, the present invention is directed to a method for controlling the connection speed of downhole connectors in a subterranean well. The method includes positioning a first assembly having a first downhole connector and a first communication medium in the well; engaging the first assembly with a second assembly, the second assembly including a second downhole connector and a second communication medium, the second assembly having an outer portion and an inner portion that are initially coupling together; unlocking the outer portion of the second assembly from the inner portion of the second assembly responsive to contact with the first assembly; axially shifting the outer portion of the second assembly relative to the inner portion of the second assembly; operatively connecting the first and second downhole connectors, thereby enabling communication between the first and second communication media; and resisting disconnection of the first and second downhole connectors by recoupling the outer portion of the second assembly with the inner portion of the second assembly. 
     In another additional aspect, the present invention is directed to an apparatus for controlling the connection speed of downhole connectors in a subterranean well. The apparatus includes a first assembly having a first downhole connector and a first communication medium that is positionable in the well. A second assembly includes a second downhole connector and a second communication medium. The second assembly has an outer portion and an inner portion that are selectively axially shiftable relative to one another. A first lock assembly initially couples the outer and inner portions of the second assembly together. A second lock assembly is operable to recouple the outer and inner portions of the second assembly together. In operation, upon engagement of the first assembly with the second assembly, the first lock assembly is released to allow axial shifting of the outer portion of the second assembly relative to the inner portion of the second assembly in a first direction which operatively connects the first and second downhole connectors, thereby enabling communication between the communication media. Thereafter, continued axial shifting of the outer portion of the second assembly relative to the inner portion of the second assembly in the first direction engages the second lock assembly thereby recoupling the outer portion of the second assembly with the inner portion of the second assembly to resist disconnection of the first and second downhole connectors. 
    
    
     
       BRIEF DESCRIPTION OF THE DRAWINGS 
       For a more complete understanding of the features and advantages of the present invention, reference is now made to the detailed description of the invention along with the accompanying figures in which corresponding numerals in the different figures refer to corresponding parts and in which: 
         FIG. 1  is a schematic illustration of an offshore oil and gas platform operating an apparatus for controlling the connection speed of downhole connectors according to an embodiment of the present invention; 
         FIGS. 2A-2D  are front views of consecutive axial sections of an apparatus for controlling the connection speed of downhole connectors in a running configuration according to an embodiment of the present invention; 
         FIGS. 3A-3D  are cross sectional views of consecutive axial sections of an apparatus for controlling the connection speed of downhole connectors in a running configuration according to an embodiment of the present invention; 
         FIGS. 4A-4D  are front views of consecutive axial sections of an apparatus for controlling the connection speed of downhole connectors in an anchored configuration according to an embodiment of the present invention; 
         FIGS. 5A-5D  are cross sectional views of consecutive axial sections of an apparatus for controlling the connection speed of downhole connectors in an anchored configuration according to an embodiment of the present invention; 
         FIGS. 6A-6C  and  7 A- 7 C are front views turned 90 degrees relative to one another of consecutive axial sections of an apparatus for controlling the connection speed of downhole connectors according to an embodiment of the present invention; 
         FIGS. 8A-8C  and  9 A- 9 C are cross sectional views turned 90 degrees relative to one another of consecutive axial sections of an apparatus for controlling the connection speed of downhole connectors in a running configuration according to an embodiment of the present invention; 
         FIGS. 10A-10C  and  11 A- 11 C are cross sectional views turned 90 degrees relative to one another of consecutive axial sections of an apparatus for controlling the connection speed of downhole connectors in an unlocked configuration according to an embodiment of the present invention; 
         FIGS. 12A-12C  and  13 A- 13 C are cross sectional views turned 90 degrees relative to one another of consecutive axial sections of an apparatus for controlling the connection speed of downhole connectors in a connected configuration according to an embodiment of the present invention; 
         FIGS. 14A-14C  and  15 A- 15 C are cross sectional views turned 90 degrees relative to one another of consecutive axial sections of an apparatus for controlling the connection speed of downhole connectors in a fully compressed configuration according to an embodiment of the present invention; 
         FIGS. 16A-16C  and  17 A- 17 C are cross sectional views turned 90 degrees relative to one another of consecutive axial sections of an apparatus for controlling the connection speed of downhole connectors in a locked configuration according to an embodiment of the present invention; and 
         FIGS. 18A-18C  are cross sectional views of a lock assembly section of an apparatus for controlling the connection speed of downhole connectors in various configurations according to an embodiment of the present invention. 
     
    
    
     DETAILED DESCRIPTION OF THE INVENTION 
     While the making and using of various embodiments of the present invention are discussed in detail below, it should be appreciated that the present invention provides many applicable inventive concepts, which can be embodied in a wide variety of specific contexts. The specific embodiments discussed herein are merely illustrative of specific ways to make and use the invention, and do not delimit the scope of the invention. 
     Referring initially to  FIG. 1 , an apparatus for controlling the connection speed of downhole connectors deployed from an offshore oil or gas platform is schematically illustrated and generally designated  10 . A semi-submersible platform  12  is centered over submerged oil and gas formation  14  located below sea floor  16 . A subsea conduit  18  extends from deck  20  of platform  12  to wellhead installation  22 , including blowout preventers  24 . Platform  12  has a hoisting apparatus  26 , a derrick  28 , a travel block  30 , a hook  32  and a swivel  34  for raising and lowering pipe strings, such as a substantially tubular, axially extending production tubing  36 . 
     A wellbore  38  extends through the various earth strata including formation  14 . An upper portion of wellbore  38  includes casing  40  that is cemented within wellbore  38 . Disposed in an open hole portion of wellbore  38  is a completion  42  that includes various tools such as packer  44 , a seal bore assembly  46  and sand control screen assemblies  48 ,  50 ,  52 ,  54 . In the illustrated embodiment, completion  42  also includes an orientation and alignment subassembly  56  that houses a downhole wet mate connector. Extending downhole from orientation and alignment subassembly  56  is a conduit  58  that passes through packer  44  and is operably associated with sand control screen assemblies  48 ,  50 ,  52 ,  54 . Preferably, conduit  58  is a spoolable metal conduit, such as a stainless steel conduit that may be attached to the exterior of pipe strings as they are deployed in the well. In the illustrated embodiment, conduit  58  is wrapped around sand control screen assemblies  48 ,  50 ,  52 ,  54 . One or more communication media such as optical fibers, electrical conducts, hydraulic fluid or the like may be disposed within conduit  58 . In certain embodiments, the communication media may operate as energy conductors that are operable to transmit power and/or data between downhole components such as downhole sensors (not pictured) and the surface. In other embodiments, the communication media may operate as downhole sensors. 
     For example, when optical fibers are used as the communication media, the optical fibers may be used to obtain distributed measurements representing a parameter along the entire length of the fiber such as distributed temperature sensing. In this embodiment, a pulse of laser light from the surface is sent along the fiber and portions of the light are backscattered to the surface due to the optical properties of the fiber. The slightly shifted frequency of the backscattered light provides information that is used to determine the temperature at the point in the fiber where the backscatter originated. In addition, as the speed of light is constant, the distance from the surface to the point where the backscatter originated can also be determined. In this manner, continuous monitoring of the backscattered light will provide temperature profile information for the entire length of the fiber. 
     Disposed in wellbore  38  at the lower end of production tubing string  36  are a variety of tools including seal assembly  60  and anchor assembly  62  including downhole wet mate connector  64 . Extending uphole of connector  64  is a conduit  66  that extends to the surface in the annulus between production tubing string  36  and wellbore  38  and is suitable coupled to production tubing string  36  to prevent damage to conduit  66  during installation. Similar to conduit  58 , conduit  66  may have one or more communication media, such as optical fibers, electrical conducts, hydraulic fluid or the like disposed therein. Preferable, conduit  58  and conduit  66  will have the same type of communication media disposed therein such that energy may be transmitted therebetween following the connection process. As discussed in greater detail below, prior to producing fluids, such as hydrocarbon fluids, from formation  14 , production tubing string  36  and completion  42  are connected together. When properly connected to each other, a sealed communication path is created between seal assembly  60  and seal bore assembly  46  which establishes a sealed internal flow passage from completion  42  to production tubing string  36 , thereby providing a fluid conduit to the surface for production fluids. In addition, as discussed in greater detail below, the present invention enables the communication media associated with conduit  66  to be operatively connected to the communication media associated with conduit  58 , thereby enabling communication therebetween and, in the case of optical fiber communication media, enabling distributed temperature information to be obtained along completion  42  during the subsequent production operations. 
     Even though  FIG. 1  depicts a slanted wellbore, it should be understood by those skilled in the art that the apparatus for controlling the connection speed of downhole connectors according to the present invention is equally well suited for use in wellbore having other orientations including vertical wellbores, horizontal wellbores, multilateral wellbores or the like. Accordingly, it should be understood by those skilled in the art that the use of directional terms such as above, below, upper, lower, upward, downward and the like are used in relation to the illustrative embodiments as they are depicted in the figures, the upward direction being toward the top of the corresponding figure and the downward direction being toward the bottom of the corresponding figure. Also, even though  FIG. 1  depicts an offshore operation, it should be understood by those skilled in the art that the apparatus for controlling the connection speed of downhole connectors according to the present invention is equally well suited for use in onshore operations. Further, even though  FIG. 1  depicts an open hole completion, it should be understood by those skilled in the art that the apparatus for controlling the connection speed of downhole connectors according to the present invention is equally well suited for use in cased hole completions. 
     Referring now to  FIGS. 2 and 3 , including  FIGS. 2A-2D  and  FIGS. 3A-3D , therein is depicted successive axial section of an apparatus for controlling the connection speed of downhole connectors that is generally designated  100 . It is noted that  FIGS. 2A-2D  and  FIGS. 3A-3D  as well as  FIGS. 4A-4D  and  5 A- 5 D below are described with reference to optical fibers as the communication media. As discussed above, those skilled in the art will recognize that the present invention is not limited to this illustrated embodiment but instead encompasses other communication media including, but not limited to, electrical conductors and hydraulic fluid. Also, as described above, apparatus  100  is formed from certain components that are initially installed downhole as part of completion  42  and certain components that are carried on the lower end of production tubing string  36 . As illustrated in  FIG. 2 , some the components carried on the lower end of production tubing string  36  have come in contact with certain components of completion  42  prior to connecting the respective wet mate connectors together. The entire apparatus  100  will now be described from its uphole end to its downhole end, first describing the exterior parts of the components carried on the lower end of production tubing string  36 , followed by the interior parts of the components carried on the lower end of production tubing string  36  then describing the components previously installed downhole as part of completion  42 . 
     Apparatus  100  includes a substantially tubular axially extending upper connector  102  that is operable to be coupled to the lower end of production tubing string  36  by threading or other suitable means. At its lower end, upper connector  102  is threadedly and sealingly connected to the upper end of a substantially tubular axially extending hone bore  104 . Hone bore  104  includes a plurality of lateral opening  106  having plugs  108  disposed therein. At its lower end, hone bore  104  is securably connected to the upper end of a substantially tubular axially extending connector member  110 . At its lower end, connector member  110  is securably connected to the upper end of an axially extending collet assembly  112 . Collet assembly  112  includes a plurality of circumferentially disposed anchor collets  114 , each having an upper surface  116 . In addition, collet assembly  112  includes a plurality of circumferentially disposed unlocking collets  118 . Further, collet assembly  112  includes a plurality of radially inwardly extending protrusions  120  and profiles  122 . At its lower end, collet assembly  112  is threadedly coupled to the upper end of a substantially tubular axially extending key retainer  124 . A portion of collet assembly  112  and key retainer  124  are both slidably disposed about the upper end of a substantially tubular axially extending key mandrel  126 . Key mandrel  126  includes a key window  128  into which a spring key  130  is received. 
     At its lower end, key mandrel  126  is threadedly coupled to the upper end of a substantially tubular axially extending spring housing  132 . Disposed within spring housing  132  is an axially extending spiral wound compression spring  134 . At its lower end, spring housing  132  is slidably disposed about the upper end of a substantially tubular axially extending connector member  136 . At its lower end, connector member  136  is threadedly coupled to the upper end of a substantially tubular axially extending splitter  138 . Splitter  138  includes an orientation key  140  disposed about a circumferential portion of splitter  138 . At its lower end, splitter  138  is coupled to the upper end of a substantially tubular axially extending fiber optic wet mate head  142  by threading, bolting or other suitable technique. Fiber optic wet mate head  142  includes a plurality of guide members  144 . In the illustrated embodiment, fiber optic wet mate head  142  has three fiber optic wet mate connectors  146  disposed therein. Each of the fiber optic wet mate connectors  146  has an optical fiber disposed therein. As illustrated, the three optical fibers associated with fiber optic wet mate connectors  146  passed through splitter  138  and are housed within a single conduit  148  that wraps around connector member  136  and extends uphole along the exterior of apparatus  100 . Conduit  148  is secured to apparatus  100  by banding or other suitable technique. 
     In the previous section, the exterior components of the portion of apparatus  100  carried by production tubing string  36  were described. In this section, the interior components of the portion of apparatus  100  carried by production tubing string  36  will be described. At its upper end, apparatus  100  includes a substantially tubular axially extending piston mandrel  200  that is slidably and sealingly received within upper connector  102 . Disposed between piston mandrel  200  and hone bore  104  is an annular oil chamber  202  including upper section  204  and lower section  206 . Securably attached to piston mandrel  200  and sealing positioned within annular oil chamber  202  is a transfer piston  208 . Transfer piston  208  includes one or more passageways  210  therethrough which preferably include orifices that regulate the rate at which a transfer fluid such as a liquid or gas and preferably an oil disposed within annular oil chamber  202  may travel therethrough. Preferably, a check valve may be disposed within each passageway  210  to allow the flow of oil to proceed in only one direction through that passageway  210 . In this embodiment, certain of the check valves will allow fluid flow in the uphole direction while other of the check valves will allow fluid flow in the downhole direction. In this manner, the resistance to flow in the downhole direction can be different from the resistance to flow in the uphole direction which respectively determines the speed of coupling and decoupling of the downhole connectors of apparatus  100 . For example, it may be desirable to couple the downhole connectors at a speed that is slower than the speed at which the downhole connectors are decoupled. 
     Disposed within annular oil chamber  202  is a compensation piston  212  that has a sealing relationship with both the inner surface of hone bore  104  and the outer surface of piston mandrel  200 . At its lower end, piston mandrel  200  is threadedly and sealingly coupled to the upper end of a substantially tubular axially extending key block  214 . Key block  214  has a radially reduced profile  216  into which spring mounted locking keys  218  are positioned. Locking keys  218  include a profile  220 . At its lower end, key block  214  is threadedly and sealingly coupled to the upper end of a substantially tubular axially extending bottom mandrel  222 . Bottom mandrel  222  includes a groove  224 . A pickup ring  226  is positioned around bottom mandrel  222 . Positioned near the lower end of bottom mandrel  222  is a key carrier  228  that has a no go surface  230 . Disposed within key carrier  228  is a spring mounted locking key  232 . Positioned between key carrier  228  and bottom mandrel  222  is a torque key  234 . At its lower end, bottom mandrel  222  is threadedly and sealingly coupled to the upper end of a substantially tubular axially extending seal adaptor  236 . At its lower end, seal adaptor  236  is threadedly and sealingly coupled to the upper end of one or more substantially tubular axially extending seal assemblies (not pictured) that establish a sealing relationship with an interior surface of completion  42 . 
     In the previous two sections, the components of apparatus  100  carried by production tubing string  36  were described. Collectively, these components may be referred to as an anchor or anchoring assembly. In this section, the components of apparatus  100  installed with completion  42  will be described. Apparatus  100  includes an orientation and alignment subassembly  300  that includes a locating and orienting guide  302  that is illustrated in  FIG. 3  but has been removed from  FIG. 2  for clarity of illustration. Locating and orienting guide  302  includes a locking profile  304 , a groove  306  and a plurality of fluid passageways  308 . In addition, locating and orienting guide  302  includes a receiving slot  310 . Disposed within locating and orienting guide  302 , orientation and alignment subassembly  300  includes a top subassembly  312  that supports a fiber optic wet mate holder  314 . In the illustrated embodiment, disposed within wet mate holder  314  are three wet mate connectors  316 . At its upper end, wet mate holder  314  includes a plurality of guides  318 . Positioned between top subassembly  312  and locating and orienting guide  302  is a key  320 . At its lower end, top subassembly  312  is threadedly and sealingly coupled to the upper end of a substantially tubular axially extending splitter  322 . At its lower end, splitter  322  is coupled to the upper end of one or more substantially tubular axially extending packers  324  by threading, bolting, fastening or other suitable technique. Each of the fiber optic wet mate connectors  316  has an optical fiber disposed therein. As illustrated, the three optical fibers associated with fiber optic wet mate holder  314  pass through splitter  322  and are housed within a single conduit  326  that extends through packer  324  and is wrapped around sand control screens  48 ,  50 ,  52 ,  54  as described above to obtain distributed temperature information, for example. 
     The operation of the apparatus for controlling the connection speed of downhole connectors according to the present invention will now be described. After the installation of completion  42  in the wellbore and the performance of any associated treatment processes wherein the optical fibers associated with completion  42  and companion optical fibers associated with the service tool string may deliver information to the surface, the service tool string is retrieved to the surface. In this process, the optical fibers associated with completion  42  and the optical fibers associated with the service tool string must be decoupled. In order to reuse the optical fibers associated with completion  42  during production, new optical fibers must be carried with production tubing string  36  and optically coupled to the optical fibers associated with completion  42 . 
     In the present invention, conduit  148  is attached to the exterior of production tubing string  36  and extends from the surface to the anchor assembly. One or more optical fibers are disposed within conduit  148  which may be a conventional hydraulic line formed from stainless steel or similar material. The anchor assembly is lowered into the wellbore until the seal assemblies on its lower end enter completion  42 . As production tubing string  36  is further lowered into the wellbore, orientation key  140  contacts the inclined surfaces of locating and orientating guide  302 . This interaction rotates the anchor assembly until orientation key  140  locates within slot  310  which provides a relatively coarse circumferential alignment of fiber optic wet mate head  142  with fiber optic wet mate holder  314 . The anchor assembly now continues to travel downwardly in completion  42  until no go surface  230  of key carrier  228  contacts an upwardly facing shoulder  328  of top subassembly  312 . Prior to contact between no go surface  230  and upwardly facing shoulder  328 , guides  144  of fiber optic wet mate head  142  and guides  318  of fiber optic wet mate holder  314  interact to provide more precise circumferential and axially alignment of the assemblies. 
     Once no go surface  230  contacts upwardly facing shoulder  328 , further downward motion of the inner components of the anchor assembly stops. In this configuration, as best seen in  FIGS. 2A-2D  and  3 A- 3 D, unlocking collets  118  are radially inwardly shifted due to contact with the inner surface of locating and orienting guide  302 . This radially inward shifting causes the inner surfaces of unlocking collets  118  to contact unlocking keys  218  and compress the associated springs causing unlocking keys  218  to radially inwardly retract. In the retraced position, radially inwardly extending protrusions  120  are released from profile  220 , thereby decoupling the outer portions of the anchor assembly from the inner portions of the anchor assembly. Relative axially movement of the outer portions of the anchor assembly and the inner portions of the anchor assembly is now permitted. 
     As continued downward force is placed on the anchor assembly by applying force to the production tubing string  36 , upper connector  102  is urged downwardly relative to piston mandrel  200 . The movement of upper connector  102  relative to piston mandrel  200  is resisted, however, by a resistance member. In the illustrated embodiment, the resistance member is depicted as transfer piston  208  and the fluid within annular oil chamber  202 . Specifically, the speed at which upper connector  102  can move relative to piston mandrel  200  is determined by the size of the orifice within passageway  210  of transfer piston  208  as well as the type of fluid, including liquids, gases or combinations thereof, within annular oil chamber  202 . As the downward force is applied to upper connector  102 , the fluid from upper section  204  of annular oil chamber  202  transfers to lower section  206  of annular oil chamber  202  passing through passageway  210 . In this manner, excessive connection speed of fiber optic wet mate connectors  146  and fiber optic wet mate connectors  316  is prevented. Even though the resistance member has been described as transfer piston  208  and the fluid within annular oil chamber  202 , it should be understood by those skilled in the art that other types of resistance members could alternatively be used and are considered within the scope of the present invention, including, but not limited to, mechanical springs, fluid springs, fluid dampeners, shock absorbers and the like. 
     As best seen in  FIGS. 4A-4D  and  5 A- 5 D, continued downward force on upper connector  102  not only enables connection of fiber optic wet mate connectors  146  and fiber optic wet mate connectors  316 , but also, compresses the outer components of the anchor assembly and locks the anchor assembly within completion  42 . Once the connection between fiber optic wet mate connectors  146  and fiber optic wet mate connectors  316  is established, thereby permitting light transmission between the optical fibers therein, continued downward force on upper connector  102  compresses spring  134 . As spring  134  is compressed, spring housing  132  telescopes relative to connector member  136 . This shortening of the outer components of the anchor assembly allows spring key  130  to engage groove  224  of bottom mandrel  222 . Once spring key  130  has radially inwardly retracted, the outer components of the anchor assembly further collapse as collet assembly  112  and key retainer  124  telescope relative to key mandrel  126 . This shortening allows anchor collets  114  to engage locking profile  304  which couples the anchor assembly within completion  42 . Also, this shortening allows unlocking collets  118  to engage groove  306  which relaxes unlocking collets  118 . In addition, the inner portions of the anchor assembly are independently secured within completion  42  as extension  150  on the lower end of fiber optic wet mate head  142  is positioned under locking key  232  such that locking key  232  engages profile  330  of top subassembly  312 . 
     In this configuration, not only are fiber optic wet mate connectors  146  and fiber optic wet mate connectors  316  coupled together, there is a biasing force created by compressed spring  134  that assures the connections will not be lost. Specifically, compressed spring  134  downwardly biases connector member  136  which in turn applies a downward force on splitter  138  and fiber optic wet mate head  142 . This force prevents any decoupling of fiber optic wet mate connectors  146  and fiber optic wet mate connectors  316 . In addition, the interaction of surface  116  of anchor collets  114  with locking profile  304  of locating and orienting guide  302  prevents separation of the anchoring assembly and the completion  42 . If it is desired to detach production tubing string  36  from completion  42 , a significant tensile force must be applied to production tubing string  36  at the surface, for example, 20,000 lbs. This force is transmitted via upper connector  102 , hone bore  104  and connector member  110  to collet assembly  112 . When sufficient tensile force is provided, anchor collets  114  will release from locking profile  304 . Thereafter, the outer portions of anchor assembly that were telescopically contracted can be telescopically extended including the release of energy from spring  134 . In order to separate fiber optic wet mate connectors  146  and fiber optic wet mate connectors  316 , the outer portions of the anchor assembly must be shifted relative to the inner portions of the anchor assembly. The rate of the axial shifting is again controlled by the metering rate of fluid through transfer piston  212 . After the outer portions of the anchor assembly have been shifted relative to the inner portions of the anchor assembly, extension  150  no longer supports locking key  232  in profile  330 . As this point the entire anchor assembly may be retrieved to the surface. 
     Referring now to  FIGS. 6-9 , including  FIGS. 6A-6C ,  7 A- 7 C,  8 A- 8 C and  9 A- 9 C, therein is depicted successive axial section of an apparatus for controlling the connection speed of downhole connectors that is generally designated  400 . It is noted that  FIGS. 6A-6C  and  7 A- 7 C are multiple views of the same apparatus turned 90 degrees relative to one another with the downhole part of completion  42  being removed in  FIGS. 6A-6C . Likewise,  FIGS. 8A-8C  and  9 A- 9 C are multiple views of the same apparatus turned 90 degrees relative to one another. As described above, apparatus  400  is formed from certain components that are initially installed downhole as part of completion  42  and certain components that are carried on the lower end of production tubing string  36 . As illustrated in  FIGS. 7-9 , some the components carried on the lower end of production tubing string  36  have come in contact with certain components of completion  42  prior to connecting the respective wet mate connectors together. The entire apparatus  400  will now be described from its uphole end to its downhole end, first describing the exterior parts of the components carried on the lower end of production tubing string  36 , followed by the interior parts of the components carried on the lower end of production tubing string  36  then describing the components previously installed downhole as part of completion  42 . 
     Apparatus  400  includes a substantially tubular axially extending upper connector  402  that is operable to be coupled to the lower end of production tubing string  36  by threading or other suitable means. At its lower end, upper connector  402  is threadedly and sealingly connected to the upper end of a substantially tubular axially extending hone bore  404 . Hone bore  404  includes a plurality of lateral opening  406  having plugs  408  disposed therein. At its lower end, hone bore  404  is securably connected to the upper end of a substantially tubular axially extending collet assembly  410  that includes a plurality of circumferentially disposed locking collets  412  each having a radially inwardly extending protrusion  414  with an upper surface  416 . At its lower end, collet assembly  410  is threadedly coupled to the upper end of a substantially tubular axially extending spring housing  418 . Disposed within spring housing  418  is an axially extending spiral wound compression spring  420 . Spring housing  418  includes an annular groove  422 . At its lower end, spring housing  418  is slidably disposed about the upper end of a substantially tubular axially extending spring support member  424  that include a plurality of windows  426  having keys  428  positioned therein. A debris housing  430  is positioned around spring housing  418  and spring support member  424 . 
     At its lower end, spring support member  424  is threadedly coupled to the upper end of a substantially tubular axially extending fiber optic wet mate head  432 . Fiber optic wet mate head  432  includes an orientation guide  434  that preferably has opposing helical surfaces  436 ,  438 . Fiber optic wet mate head  432  includes a plurality of guide members  440 . In the illustrated embodiment, fiber optic wet mate head  432  has three fiber optic wet mate connectors  442  disposed therein. Each of the fiber optic wet mate connectors  442  has an optical fiber disposed therein. As illustrated, the three optical fibers associated with fiber optic wet mate connectors  442  may pass through a splitter such that they are housed within a single conduit  444  that extends uphole from apparatus  400  to the surface. Conduit  444  may be secured to apparatus  400  by any suitable means such as banding or similar technique. At its lower end, fiber optic wet mate head  432  includes a prop member  446 . Slidably received in a pair of slots in fiber optic wet mate head  432  is a pair of plungers  448 ,  450  which are individually biased by a pair of springs  452 ,  454 . 
     In the previous section, the exterior components of the portion of apparatus  400  carried by production tubing string  36  were described. In this section, the interior components of the portion of apparatus  400  carried by production tubing string  36  will be described. At its upper end, apparatus  400  includes a substantially tubular axially extending piston mandrel  500  that is slidably and sealingly received within upper connector  402 . Disposed between piston mandrel  500  and hone bore  404  is an annular oil chamber  502  including upper section  504  and lower section  506 . Securably attached to piston mandrel  500  and sealing positioned within annular oil chamber  502  is a transfer piston  508 . Transfer piston  508  includes one or more passageways  510  therethrough which preferably include orifices that regulate the rate at which a transfer fluid, such as a liquid or gas and preferably an oil disposed within annular oil chamber  502 , may travel therethrough. Preferably, a check valve may be disposed within each passageway  510  to allow the flow of oil to proceed in only one direction through that passageway  510 . In this embodiment, certain of the check valves will allow fluid flow in the uphole direction while other of the check valves will allow fluid flow in the downhole direction. In this manner, the resistance to flow in the downhole direction can be different from the resistance to flow in the uphole direction which respectively determines the speed of coupling and decoupling of the downhole connectors of apparatus  400 . For example, it may be desirable to couple the downhole connectors at a speed that is slower than the speed at which the downhole connectors are decoupled. 
     Disposed within annular oil chamber  502  is a compensation piston  512  that has a sealing relationship with both the inner surface of hone bore  404  and the outer surface of piston mandrel  500 . At its lower end, piston mandrel  500  is threadedly and sealingly coupled to the upper end of a substantially tubular axially extending locking profile assembly  514  that includes a radially outwardly extending annular protrusion  516  having a shoulder  518 . Together, locking profile assembly  514  and locking collets  412  may be referred to herein as a lock assembly. At its lower end, locking profile assembly  514  is threadedly and sealingly coupled to the upper end of a substantially tubular axially extending bottom mandrel  520 . Bottom mandrel  520  includes a radially inwardly extending groove  522 . A pickup ring  524  is positioned around bottom mandrel  520 . A pair of spring operated lugs  526 ,  528  is received within a pair of radially reduces sections of bottom mandrel  520 . Together, spring operated lugs  526 ,  528  and plungers  448 ,  450  may be referred to herein as a lock assembly. Positioned near the lower end of bottom mandrel  520  is a key assembly  530  that has a locator surface  532  and a plurality of locking keys  534 . At its lower end, bottom mandrel  520  is threadedly and sealingly coupled to the upper end of a substantially tubular axially extending seal adaptor  536 . At its lower end, seal adaptor  536  is threadedly and sealingly coupled to the upper end of one or more substantially tubular axially extending seal assemblies (not pictured) that establish a sealing relationship with an interior surface of completion  42 . 
     In the previous two sections, the components of apparatus  400  carried by production tubing string  36  were described. Collectively, these components may be referred to as an anchor or anchoring assembly. In this section, the components of apparatus  400  installed with completion  42  will be described. Apparatus  400  includes an orienting guide  600  that has a plurality of fluid passageways  602 . In addition, orienting guide  600  preferably has opposing helical surfaces  604 ,  606 . Disposed within orienting guide  600  is a top subassembly  608  that supports a fiber optic wet mate holder  612 . In the illustrated embodiment, disposed within wet mate holder  612  are three wet mate connectors  614 . At its upper end, wet mate holder  612  includes a plurality of guides  616 . Top subassembly  608  has a radially reduced section  618  having a frustoconical surface  620  and a frustoconical surface  622 . In addition, at its upper end, top subassembly  608  has a frustoconical surface  628 . Each of the fiber optic wet mate connectors  614  has an optical fiber disposed therein. As illustrated, the three optical fibers associated with fiber optic wet mate holder  614  may pass through a splitter such that they may be housed within a single conduit that extends through a packer disposed below apparatus  400  and is wrapped around sand control screens  48 ,  50 ,  52 ,  54  as described above to obtain distributed temperature information, for example. 
     The operation of this embodiment of an apparatus for controlling the connection speed of downhole connectors according to the present invention will now be described. After the installation of completion  42  in the wellbore and the performance of any associated treatment processes wherein the optical fibers associated with completion  42  and companion optical fibers associated with the service tool string may deliver information to the surface, the service tool string is retrieved to the surface. In this process, the optical fibers associated with completion  42  and the optical fibers associated with the service tool string must be decoupled. In order to reuse the optical fibers associated with completion  42  during production, new optical fibers must be carried with production tubing string  36  and optically coupled to the optical fibers associated with completion  42 . 
     In the present invention, conduit  444  is attached to the exterior of production tubing string  36  and extends from the surface to the anchor assembly. One or more optical fibers are disposed within conduit  444  which may be a conventional hydraulic line formed from stainless steel or similar material. The anchor assembly is lowered into the wellbore until the seal assemblies on its lower end enter completion  42 . As production tubing string  36  is further lowered into the wellbore, orientation guide  434  contacts orientating guide  600 . This interaction rotates the anchor assembly to provide a relatively coarse circumferential alignment of fiber optic wet mate head  432  with fiber optic wet mate holder  612 . The anchor assembly now continues to travel downwardly in completion  42  until plungers  448 ,  450  contact surface  628  of top subassembly  608 . Further downward motion of the anchor assembly causes plungers  448 ,  450  to shift longitudinally relative to fiber optic wet mate head  432  and compress springs  452 ,  454 . In addition, this longitudinal movement causes lugs  526 ,  528  to shift radially inwardly, as best seen in  FIGS. 10A-10C  and  11 A- 11 C. This action unlocks the inner components of the anchor assembly from the outer components of the anchor assembly. As further downward movement of the inner components of the anchor assembly is now prevented by contact between surface  532  of key assembly  530  and surface  620  of top subassembly  608 , weight applied to apparatus  400  causes the outer components of the anchor assembly to shift longitudinally relative to the inner components of the anchor assembly in a telescopic manner. 
     As continued downward force is placed on the anchor assembly by applying force to the production tubing string  36 , upper connector  402  is urged downwardly relative to piston mandrel  500 . The movement of upper connector  402  relative to piston mandrel  500  is resisted, however, by a resistance member. In the illustrated embodiment, the resistance member is depicted as transfer piston  508  and the fluid within annular oil chamber  502 . Specifically, the speed at which upper connector  402  can move relative to piston mandrel  500  is determined by the size of the orifices within passageways  510  of transfer piston  508  as well as the type of fluid, including liquids, gases or combinations thereof, within annular oil chamber  502 . As the downward force is applied to upper connector  402 , the fluid from upper section  504  of annular oil chamber  502  transfers to lower section  506  of annular oil chamber  502  passing through passageways  510 . In this manner, excessive connection speed of fiber optic wet mate connectors  442  and fiber optic wet mate connectors  614  is prevented. 
     As best seen in  FIGS. 12A-12C  and  13 A- 13 C, continued downward force on upper connector  402  not only enables connection of fiber optic wet mate connectors  442  and fiber optic wet mate connectors  614  at a predetermined speed, but also, causes prop member  446  of fiber optic wet mate head  432  to prop locking keys  534  of key assembly  530  in radially reduced section  618  of top subassembly  608  which anchors the inner components of the anchor assembly within completion  42 . In addition, this telescopic movement of the outer components of the anchor assembly relative to the inner components of the anchor assembly causes keys  428  to become aligned with annular groove  522  of bottom mandrel  520 . In this configuration, keys  428  are released from annular groove  422  of spring housing  418 . Once the connection between fiber optic wet mate connectors  442  and fiber optic wet mate connectors  614  is established, light transmission is permitted between the optical fibers therein. 
     As best seen in  FIGS. 14A-14C  and  15 A- 15 C, continued downward force applied on upper connector  402  further shifts the outer components of the anchor assembly relative to the inner components of the anchor assembly. In this configuration, the telescopic movement causes locking collets  412  to pass downwardly over annular protrusion  516  of locking profile assembly  514  while spring  420  is being compressed between collet assembly  410  and spring support member  424 . Once apparatus  400  is in this configuration, the downward force applied on upper connector  402  may be release such that apparatus  400  will be placed in its production configuration, as best seen in  FIGS. 16A-16C  and  17 A- 17 C. In this configuration, not only are fiber optic wet mate connectors  442  and fiber optic wet mate connectors  614  coupled together, there is a biasing force created by compressed spring  420  that assures the connections will not be lost. Specifically, compressed spring  420  downwardly biases spring support member  424  which in turn applies a downward force on fiber optic wet mate head  432 . This force prevents any decoupling of fiber optic wet mate connectors  442  and fiber optic wet mate connectors  614 . In addition, the interaction between locking keys  534  of key assembly  530  and top subassembly  408  prevents separation of the anchoring assembly and the completion  42 . 
     If it is desired to detach production tubing string  36  from completion  42 , a significant tensile force must be applied to production tubing string  36  at the surface, for example, 20,000 lbs. This force is transmitted via upper connector  402  and hone bore  404  to collet assembly  410 . The upward force acts between surfaces  416  of locking collets  412  and shoulder  518  of locking profile assembly  514 . As upward movement of locking profile assembly  514  is prevented by the interaction between locking keys  534  of key assembly  530  and top subassembly  608 , upon application of sufficient force, locking collets  412  will release from locking profile assembly  514 . Thereafter, the outer portions of anchor assembly that were telescopically contracted can be telescopically extended including the release of energy from spring  420 . In order to separate fiber optic wet mate connectors  442  and fiber optic wet mate connectors  614 , the outer portions of the anchor assembly must be further shifted relative to the inner portions of the anchor assembly. The rate of the axial shifting is again controlled by the metering rate of fluid through transfer piston  508 . To aid in full extension of the outer portions of the anchor assembly relative to the inner portions of the anchor assembly, an optional spring  538  may operate between upper connector  402  and transfer piston  508 . As this point the anchor assembly returns to the running configuration as seen in  FIGS. 8A-8C  and  9 A- 9 C and may be retrieved to the surface or the set down and latch up sequence can be started again. 
     Referring next to  FIGS. 18A-18C , therein is depicted another embodiment of an apparatus for controlling the connection speed of downhole connectors that is generally designated  700 . In the portion of apparatus  700  that is depicted, an alternate embodiment of a lock assembly will be described. In the illustrated section, apparatus  700  includes a portion of an anchor assembly  702  and a portion of a completion  704 . Apparatus  700  is similar to apparatus  400  described above except for the configuration and operation of the lock assembly  706  that releases the outer components of the anchor assembly  702  from the inner components of the anchor assembly  702 . The outer components of anchor assembly  702  include fiber optic wet mate head  708  that has a pair of radially extending openings  710 ,  712  having lug extensions  714 ,  716  slidably positioned therein and partially extending radially outwardly therefrom. The inner components of anchor assembly  702  include bottom mandrel  718  having a pair of radially reduces sections with a pair of spring operated lugs  720 ,  722  received therein. Together, spring operated lugs  720 ,  722  and lug extensions  714 ,  716  may be referred to herein as lock assembly  706 . The inner components of anchor assembly  702  also include a key assembly  724  that is operable to engage with a profile  726  of top subassembly  728 . 
     In operation, anchor assembly  702  is lowered into the wellbore until the seal assemblies on its lower end enter completion  704 . As production tubing string  36  is further lowered into the wellbore, anchor assembly  702  may be orientated relative to completion  704  in a manner similar to that described above. Anchor assembly  702  now continues to travel downwardly in completion  704  until lug extensions  714 ,  716  reach an upper surface of completion  704  such as an upper surface of the orientation guide, as best seen in  FIG. 18A . Further downward motion of the anchor assembly  702  causes lug extensions  714 ,  716  to shift radially inwardly relative to fiber optic wet mate head  708 . In addition, this radial movement causes lugs  720 ,  722  to shift radially inwardly, as best seen in  FIG. 18B . This action unlocks the inner components of the anchor assembly from the outer components of the anchor assembly. As further downward movement of the inner components of anchor assembly  702  is now prevented by contact between key assembly  724  and top subassembly  728 , weight applied to apparatus  700  causes the outer components of anchor assembly  702  to shift longitudinally relative to the inner components of anchor assembly  702  in a telescopic manner, as best seen in  FIG. 18C , wherein key assembly  724  is propped within profile  726  of top subassembly  728 . In addition, this downward movement of the outer components of anchor assembly  702  relative to the inner components of anchor assembly  702  also causes coupling of the associated wet mate components (not visible in  FIGS. 18A-18C ) in a manner similar to that described above with reference to apparatus  400 . 
     While this invention has been described with reference to illustrative embodiments, this description is not intended to be construed in a limiting sense. Various modifications and combinations of the illustrative embodiments as well as other embodiments of the invention will be apparent to persons skilled in the art upon reference to the description. It is, therefore, intended that the appended claims encompass any such modifications or embodiments.

Summary:
Apparatuses and methods for controlling the connection speed of downhole connectors in a subterranean well are disclosed. An apparatus includes a first assembly having a first downhole connector and a first communication medium that is positionable in the well. A second assembly includes a second downhole connector and a second communication medium and has an outer portion and an inner portion that are selectively axially shiftable relative to one another. A lock assembly including at least one lug initially couples the outer and inner portions of the second assembly together such that, upon engagement of the first assembly with the second assembly downhole, the lug is radially shifted releasing the lock assembly to allow axial shifting of the outer portion of the second assembly relative to the inner portion of the second assembly, thereby operatively connecting the first and second downhole connectors to enable communication between the communication media.