Abstract:
An apparatus ( 100 ) for controlling the connection speed of downhole connectors ( 316, 146 ) in a subterranean well. The apparatus ( 100 ) includes a first assembly that is positionable in the well. The first assembly includes a first downhole connector ( 316 ) and a first communication medium. A second assembly includes a second downhole connector ( 146 ) and a second communication medium. The second assembly has an outer portion and an inner portion. The outer portion is selectively axially shiftable relative to an inner portion, such that upon engagement of the first assembly with the second assembly, the outer portion of the second assembly is axially shifted relative to the inner portion of the second assembly allowing the first and second downhole connectors ( 316, 146 ) to be operatively connected to each other, thereby enabling communication between the first communication medium and the second communication medium.

Description:
CROSS-REFERENCE TO RELATED APPLICATIONS 
     This is a continuation of co-pending application Ser. No. 12/372,862, filed Feb. 18, 2009. 
    
    
     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. As discussed above, the lower portion of the completion string may include various sensors, particularly, 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, 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 first and second downhole connectors in a subterranean well. The method includes positioning a first assembly in the well, the first assembly including the first downhole connector and a first communication medium; engaging the first assembly with a second assembly, the second assembly including the second downhole connector and a second communication medium; axially shifting an outer portion of the second assembly relative to an inner portion of the second assembly; and then operatively connecting the first and second downhole connectors to each other, thereby enabling communication between the first and second communication media. 
     In one embodiment, the method includes releasing a lock initially coupling the outer and inner portions of the second assembly. This step may be performed by radially inwardly compressing a collet assembly of the outer portion of the second assembly with an inner surface of the first assembly. In another embodiment, the method includes controlling the rate at which the outer and inner portions of the second assembly axially shift relative to one another with a resistance assembly. This step may be performed by metering a fluid through a transfer piston. In a further embodiment, the method includes anchoring the second assembly within the first assembly. This step may be performed by engaging a collet assembly of the outer portion of the second assembly with a profile of the first assembly. In yet another embodiment, the method may include disposing the first downhole connector of the first assembly at a location uphole of a packer of the first assembly. In any of the embodiments, the communication media may be optical fibers, electrical conductors, hydraulic fluid or the like. When the first communication medium is an optical fiber, this optical fiber may be operated as a sensor such as a distributed temperature sensor. 
     In another aspect, the present invention is directed to a method for controlling the connection speed of first and second fiber optic connectors in a subterranean well. The method includes positioning a first assembly in the well, the first assembly including the first fiber optic connector and a first optical fiber; engaging the first assembly with a second assembly, the second assembly including the second fiber optic connector and a second optical fiber; axially shifting an outer portion of the second assembly relative to an inner portion of the second assembly while metering a fluid through a transfer piston to control the rate at which the outer and inner portions of the second assembly axially shift relative to one another; and then operatively connecting the first and second fiber optic connectors to each other, thereby enabling light transmission between the optical fibers. 
     In a further aspect, the present invention is directed to an apparatus for controlling the connection speed of first and second downhole connectors in a subterranean well. The apparatus includes a first assembly that is positionable in the well. The first assembly includes the first downhole connector and a first communication medium. A second assembly includes the 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 such that upon engagement of the first assembly with the second assembly, the outer portion of the second assembly is axially shifted relative to the inner portion of the second assembly allowing the first and second downhole connectors to be operatively connected to each other, thereby enabling communication between the first communication medium and the second communication medium. 
     In one embodiment, the inner portion of the second assembly includes a lock and the outer portion of the second assembly includes a collet assembly. The lock initially couples the outer and inner portions of the second assembly together and the collet is operable to release the lock in response to being radially inwardly compressed by an inner surface of the first assembly. In another embodiment, the apparatus includes a resistance assembly that is positioned between the outer portion of the second assembly and the inner portion of the second assembly that controls the rate at which the outer and inner portions of the second assembly axially shift relative to one another by, for example, metering a fluid through a transfer piston. In a further embodiment, the outer portion of the second assembly includes a collet assembly and the first assembly includes a profile. In this embodiment, the collet assembly is operable to engage the profile to anchor the second assembly within the first assembly. In yet another embodiment, the first assembly includes a packer and the first downhole connector of the first assembly is positioned at a location uphole of the packer. 
     In yet another aspect, the present invention is directed to a method for controlling the disconnection speed of first and second downhole connectors in a subterranean well. The method includes establishing a predetermined tensile force between a first assembly and a second assembly in the well, the first assembly including the first downhole connector and a first communication medium, the second assembly including the second downhole connector and a second communication medium; axially shifting an outer portion of the second assembly relative to an inner portion of the second assembly; and operatively disconnecting the first and second downhole connectors from each other, thereby disabling communication between the first and second communication media. 
     In one embodiment, the method may include releasing an anchor of the second assembly from a profile in the first assembly. This step may be performed by radially inwardly compressing a collet assembly of the second assembly with an inner surface of the first assembly. In another embodiment, the method may include controlling the rate at which the outer and inner portions of the second assembly axially shift relative to one another with a resistance assembly. This step may be performed by metering a fluid through a transfer piston. 
    
    
     
       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; and 
         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. 
     
    
    
     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 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 including power and data transmission between downhole a location or 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. 
     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.