Patent Publication Number: US-6213202-B1

Title: Separable connector for coil tubing deployed systems

Description:
FIELD OF THE INVENTION 
     The present invention relates generally to the field of submergible equipment, such as pumping systems, for use in wells, such as petroleum production wells, and other submerged environments. More particularly, the invention relates to an apparatus for coupling a deployment system, such as coil tubing, to deployed equipment, such as a submergible pumping system. 
     BACKGROUND OF THE INVENTION 
     In producing petroleum and other useful fluids from production wells, a variety of component combinations, sometimes referred to as completions, are used in the downhole environment. For example, it is generally known to deploy a submergible pumping system in a well to raise the production fluids to the earth&#39;s surface. 
     In this latter example, production fluids enter the wellbore via perforations formed in a well casing adjacent a production formation. Fluids contained in the formation collect in the wellbore and are raised by the submergible pumping system to a collection point above the surface of the earth. In an exemplary submergible pumping system, the system includes several components such as a submergible electric motor that supplies energy to a submergible pump. This system may further include additional components, such as a motor protector, for isolating the motor oil from well fluids. A connector also is used to connect the submergible pumping system to a deployment system. These and other components may be combined in the overall submergible pumping system. 
     Conventional submergible pumping systems are deployed within a wellbore by a deployment system that may include tubing, cable or coil tubing. Power is supplied to the submergible electric motor via a power cable that runs along the deployment system. For example, with coil tubing, the power cable is either banded to the outside of the coil tubing or disposed internally within the hollow interior formed by the coil tubing. Additionally, other control lines, such as hydraulic control lines and tubing encapsulated conductors (TECs) may extend along or through the deployment system to provide a variety of inputs or communications with various components of the completion. 
     When an electric submergible pumping system is deployed in a well, it often is convenient to utilize coil tubing to support the completion equipment and to channel power and other conductors, particularly when production fluids are located a substantial distance beneath the earth&#39;s surface. However, the weight of the coil tubing, power cable, any fluid within the coil tubing, control lines and completion equipment determines the length of coil tubing that can support the completion in the well, eventually reaching the material strength limit of the tubing. Accordingly, it is desirable to minimize forces associated with deploying and retrieving a completion, so that the coil tubing may be deployed to maximum depth without risking damage to the coil tubing or power cable. 
     For removal of the completion from the well, such factors must be considered as adding to the load which will be exerted on the deployment system. Other loads are also encountered upon retrieval. For example, a coil tubing deployment system may be filled with an internal fluid to provide buoyancy to the power cable running therethrough. However, the “loaded” coil tubing cannot be extended as far into a well as an unloaded coil tubing deployment system, because the weight of the internal fluid places additional force on the coil tubing. The fluid also adds to the load borne by the deployment system upon retrieval. Other forces and loads may result from drag within the wellbore (such as due to integral packers and similar structures), accumulated sand or silt, rock or aggregate fall-ins, and so forth. To provide for such loads, the deployment system is generally overdesigned or the completion is positioned substantially higher in the well than the mechanical strength limits of the deployment system would otherwise dictate. 
     When a submergible pumping system is deployed to substantial depth relative to the strength of the coil tubing, it has been proposed to release the completion and remove the coil tubing from the well separately from the completion. A work string, such as a high tensile strength coil tubing with a fishing tool, is then run downhole and latched to the completion for removal. Conventionally, submergible pumping systems have been separated from the coil tubing at the connector used to connect the coil tubing to the completion. Conventional connectors had separable components connected by shear pins or other frangible structures. Thus, to release the deployment system from the submergible pumping system, sufficient force was exerted on the deployment system to shear the pins. However, the strength to withstand the additional load required to produce this shear force must also be built into the deployment system. Moreover, this additional load potentially can damage the coil tubing and power cable. To avoid such damage, the length of the coil tubing must again be reduced to correspondingly reduce the weight supported in the wellbore. Such limits on the depth to which the submergible pumping system can be deployed are undesirable. 
     It would be advantageous to have a remotely actuated separation technique for releasing a deployment system from a completion, e.g. submergible pumping system, without placing undue added forces on the deployment system during the separation operation. Such a technique for separating the deployment system from the completion would facilitate placement of the completion at greater depth within the wellbore without otherwise changing the deployment system or submergible components. 
     SUMMARY OF THE INVENTION 
     The present invention features an apparatus for connecting a submergible pumping system to a deployment system and for selectively releasing the submergible pumping system from the deployment system. In a favored configuration the system comprises a coil tubing deployment system and a downhole completion. The coil tubing deployment system is connected to the downhole completion by a connector. The connector includes an upper connector assembly and a lower connector assembly. The upper and lower connector assemblies are attached to one another. Additionally, the connector includes a separator mechanism configured for remote actuation that selectively separates the upper connector assembly from the lower connector assembly. The arrangement may be underbalanced or pressure biased into an engaged position to provide additional control on the release of the completion. The entire assembly may be field installed in a straightforward manner, thereby facilitating initial installation and deployment. 
     According to another aspect of the invention, a connector is provided for connecting a downhole completion to a deployment system. The connector comprises an upper connector assembly and a lower connector assembly attached thereto. The connector further includes a pressure chamber disposed between the upper connector assembly and the lower connector assemblies. A fluid line is disposed in fluid communication with the pressure chamber. Additionally, a check valve is connected to the fluid line. The check valve permits flow of fluid to the pressure chamber to separate the upper connector from the lower connector but prevents backflow through the fluid line after separation. 
     According to another aspect of the invention, a connector is provided for use in deploying a downhole completion. The connector includes an upper assembly and a lower assembly. A shear mechanism connects the upper assembly to the lower assembly. A plurality of conductors extend through the upper and lower assembly. Those conductors are connected across a plug having a first plug portion and a second plug portion. The connector also includes a remotely controlled separation mechanism able to simultaneously shear the shear mechanism and separate the first plug portion from the second plug portion. 
    
    
     BRIEF DESCRIPTION OF THE DRAWINGS 
     The invention will hereafter be described with reference to the accompanying drawings, wherein like reference numerals denote like elements, and: 
     FIG. 1 is a front elevational view of a submergible pumping system positioned in a wellbore, according to a preferred embodiment of the present invention; 
     FIG. 2 is a cross-sectional view of a connector, generally along its longitudinal axis according to a preferred embodiment of the present invention; 
     FIG. 3 is a cross-sectional view taken generally along line  3 — 3  of FIG. 2; 
     FIG. 4 is a cross-sectional view taken generally along line  4 — 4  of FIG. 2; 
     FIG. 5 is a cross-sectional view taken generally along line  5 — 5  of FIG. 2; 
     FIG. 6 is a cross-sectional view similar to that of FIG. 2 but showing the connector separated; 
     FIG. 7 is a vertical sectional view of a mechanically opened check valve for forcing release of the assembly shown in FIG. 2 in accordance with certain aspects of the present technique; 
     FIG. 8 is a sectional view of the valve of FIG. 7 illustrated in the installed position; 
     FIG. 9 is a sectional view of the valve of FIG. 7 following partial release of the assembly; 
     FIG. 10 is a sectional view of the valve of FIG. 7 following full release of the assembly, and with a positive pressure on the valve to purge the hydraulic supply line; 
     FIG. 11 is a sectional view of the valve of FIG. 7 following release of the purge pressure to permit the valve to reseat; 
     FIG. 12 is a sectional view of the valve of FIG. 7 adapted for transmission of fluid to a downstream component; and 
     FIG. 13 is a sectional view of the valve of FIG. 7 adapted for exchange of data or power signals with a downstream component. 
    
    
     DETAILED DESCRIPTION OF THE PREFERRED EMBODIMENTS 
     Referring generally to FIG. 1, a system  20  is illustrated according to a preferred embodiment of the present invention. System  20  may comprise a variety of components depending upon the particular application or environment in which it is used. However, system  20  typically includes a deployment system  22  connected to a completion, such as an electric submergible pumping system  24 . Deployment system  22  is attached to pumping system  24  by a connector  26 . 
     System  20  is designed for deployment in a well  28  within a geological formation  30  containing fluids, such as petroleum and water. In a typical application, a wellbore  32  is drilled and lined with a wellbore casing  34 . The submergible pumping system  24  is deployed within wellbore  32  to a desired location for pumping wellbore fluids. 
     As illustrated, pumping system  24  typically includes at least a submergible pump  36  and a submergible motor  38 . Submergible pumping system  24  also may include other components. For example, a packer assembly  40  may be utilized to provide a seal between the string of submergible components and an interior surface  42  of wellbore casing  34 . Other additional components may comprise a thrust casing  44 , a pump intake  46 , through which wellbore fluids enter pump  36 , and a motor protector  48  that serves to isolate the wellbore fluid from the motor oil. Still further components, and various configurations, may be provided depending on the characteristics of the formation and the type of well into which the completion is deployed. 
     In the preferred embodiment, deployment system  22  is a coil tubing system  50  utilizing a coil tube  52  attached to the upper end of comnector  26 . A power cable  54  runs through the hollow center of coil tube  52 . Power cable  54  typically comprises three conductors for providing power to motor  38 . Additionally, at least one control line  56  preferably runs through coil tube  52  to provide input for initiating separation of connector  26  from a remote location, as will be described in detail below. Additional lines, such as fluid or conductive control lines may run through the hollow interior of coil tube  52 . Also, other types of deployment systems may be utilized with connector  26 . 
     Referring generally to FIG. 2, a cross-sectional view of connector  26  is taken generally along its longitudinal axis. The illustrated connector  26  is a preferred embodiment of a separable connector. However, a variety of connector configurations can be utilized with the present inventive system and method. Accordingly, the present invention should not be limited to the specific details described. 
     With reference to FIG. 2, connector  26  includes an upper connector head  58  having an upper threaded region  60 . A slip nut  62  is threadably engaged with threaded region  60 . Slip nut  62  cooperates with connector head  58  and a retaining slip  64  to securely grip a lower end  66  of coil tubing  52 . A plurality of seals  68  are disposed between connector head  58  and coil tubing  52 . Additionally, a plurality of dimpling screws  70  are threaded through slip nut  62  in a radial direction for engagement with lower end  66  of coil tubing  52 . 
     In the illustrated embodiment, power cable  54  extends through the center of coil tubing  52  into a hollow interior  72  of connector  26 . Additionally, a flat pack  74 , including control line  56 , also extends through the center of coil tubing  52  into hollow interior  72 . Flat pack  74  further includes, for example, a pair of fluid lines  76  and a conductive control line  78 , such as a tubing encapsulated conductor, or TEC. 
     Power cable  54  is held within hollow interior  72  by an anchor base  80  attached to connector head  58  by a plurality of fasteners  82 , such as threaded bolts, as illustrated in FIGS. 2 and 3. Additionally, an anchor slip  84  is disposed about power cable  54  and secured by an anchor nut  86  threadably engaged with anchor base  80 . 
     An upper housing  88  is threadably engaged with connector head  58 . A hydraulic manifold  90  is disposed within upper housing  88  and held between a lower internal ridge  92  of upper housing  88  and a plate  94  (see also FIG.  4 ). Plate  94  is held against the upper end of hydraulic manifold  90  by a split sleeve  96  disposed between connector head  58  and plate  94 , as illustrated. 
     Manifold  90  includes a longitudinal opening  98  therethrough. Additionally, manifold  90  includes a plurality of fluid or conductive control line openings  100  extending longitudinally therethrough. Preferably, each opening  100  terminates at a recessed area  102  formed in manifold  90  for receiving a valve  104 . Additionally, plate  94  includes an opening through which power cable  54  and control lines  56 ,  76  and  78  extend into connection with manifold  90  via couplings  106 . 
     Disposed within opening  98  of manifold  90  is an upper plug connector  108  of an overall plug or plug assembly  110 . Upper plug connector  108 , manifold  90  and the above described components of connector  26  comprise an upper connector assembly  112  designed for separable engagement with a lower connector assembly  114 . 
     Lower connector assembly  114  includes, for example, a lower housing  116  and a lower plug connector  118  of plug  110 . Lower housing  116  and lower plug connector  118  are both designed for attachment to upper connector assembly  112 . Specifically, lower housing  116  is designed to receive the lower portion of hydraulic manifold  90 . Preferably, housing  116  is further attached to upper connector assembly  112  by a plurality of shear screws  119 , or similar controlled release elements, extending radially through lower housing  116  into manifold  90 , as illustrated in FIGS. 1 and 5. 
     Plug assembly  110  also is designed for separable engagement, such that upper plug connector  108  remains with upper connector assembly  112  and lower plug connector  118  remains with lower connector assembly  114  when connector  26  is separated. As illustrated, power cable  54  is routed to upper plug connector  108 . The power cable includes a plurality of conductors  120 , typically three motor conductors, that are routed through plug assembly  110 . Each conductor also is separable along with plug assembly  110 . For example, each conductor  120  may have a separation point formed by mating male terminals  122  and female receptacles  124  formed in corresponding portions of plug assembly  110 . Conductors  120  are designed to provide power to the completion, and in the illustrated embodiment specifically to motor  38  of the electric submergible pumping system. Thus, the plug assembly permits connector  26  to be used with powered completions without causing damage upon separation of upper connector assembly  112  and lower connector assembly  114 . Preferably, lower plug connector  118  is held within a longitudinal opening of lower housing  116  by a lower plate  126  and a support  128 . In appropriate applications, a biasing member (not shown) may be provided adjacent to one or both plug connectors to urge the connectors toward electrical engagement. Similarly, hydrostatic pressures in the acting against plate  126  may be used to bias the lower plug connector  118  into engagement with upper plug connector  108 . 
     Separation of upper connector assembly  112  from lower connector assembly  114  is accomplished by an appropriate separator mechanism. In the preferred embodiment, separator mechanism  130  comprises control line  56 , in this case a hydraulic control line, disposed through upper connector assembly  112  and manifold  90 . Separator mechanism  130  also includes valve  104  and a fluid discharge area  132  formed on lower housing  116  to create a pressure chamber  134  between upper connector assembly  112  and area  132 . For release, pressurized hydraulic fluid is forced through control line  56  from a remote location, such as a control station at the earth&#39;s surface, to pressure chamber  134 . Valve  104  permits the pressurized fluid to act against fluid discharge area  132  to pressurize pressure chamber  134 . Upon sufficient increase in pressure acting between upper connector assembly  112  and lower connector assembly  114 , the shear mechanism, e.g. shear screws  119 , is sheared. This shearing permits separation of upper connector assembly  112  from lower connector assembly  114 , as illustrated in FIG.  6 . Simultaneously, upper plug connector  108  of plug assembly  110  is disengaged from lower plug connector  118 . Thus, the connector  26  can be separated without placement of any undue force on either coil tubing  52  or power cable  54 . Following separation, the preferred embodiment illustrated provides a predicable and uniform surface or surfaces which may be engaged by a fishing tool or similar device for removal of the completion from the well. The surfaces may define various retrieval profiles, either internal or external, such as profile  117  shown in FIGS. 2 and 6. 
     Also, other separator mechanisms could be incorporated into the present design. For example, an electrical signal could be delivered downhole to a dedicated electric pump connected to and able to pressurize chamber  134 . 
     It should be noted that in the illustrated embodiment, opening  98  is disposed off the axial center of manifold  90 . With this embodiment, the shear screws  119  are grouped along the side of the manifold area that receives the greatest portion of the resultant force due to pressurized fluid flowing into pressure chamber  134 . Specifically, the placement of four shear screws, as illustrated in FIG. 5, reduces the potential for “cocking” of manifold  90  within lower housing  116 , and thereby facilitates separation of assemblies  112  and  114 . 
     Upon separation, valve  104  closes control link  56  to prevent well fluid from contaminating the hydraulic fluid within control line  56 , and to prevent wellbore fluids from escaping through the fluid lines. The preferred design and functions of valve  104  are explained in detail below. 
     Additional valves  104  may be disposed within manifold  90  for the fluid lines  76  as illustrated for control line  56  and as further described below. The use of valves  104  prevents contamination of the fluid control lines  76 , that are disposed above lower connector assembly  114 . Optionally, valves  104  can be placed in each of the control lines  76  extending along lower connector assembly  114  to prevent contamination of the control lines below upper connector assembly  112  when separated, and to prevent the escape of wellbore fluids. It also should be noted that the fluid line  76  shown beneath such additional valves  104  in FIG. 1, does not enter pressure chamber  134 . Rather, it is the continuation of one of the fluid control lines  76  that provide fluid to a desired component, such as packer assembly  40 . 
     In operation, connector  26  is attached to deployment system  22 , e.g., coil tubing  52 , and to a downhole completion, such as electric submergible pumping system  24 . Thereafter, the entire  20  system is deployed in wellbore  32  to the desired depth. In appropriate applications, it may be desirable to lock the upper connector assembly  112  to the lower connector assembly  114  during deployment and potentially during use to avoid accidental disengagement. The connector assemblies can be locked together in a variety of ways depending on the specific design of connector  26 . For example, J-slots, supported collet locks, releasable dogs or other appropriate locking mechanisms can be used. 
     After properly locating the system in the wellbore, packer assembly  40  is set via one of the lines  76 , and production fluids are pumped to the surface through the annulus formed around deployment system  22 . Preferably, any locking mechanism disposed on connector  26  is released prior to setting packer assembly  40 . When it becomes necessary to service or remove pumping system  24 , connector  26  is separated to permit removal of coil tubing  52 . 
     The separation process is initiated by pumping hydraulic fluid through control line  56  and valve  104  to fluid discharge area  132 . When the fluid pressure in control line  56  and pressure chamber  134  rises to a sufficient level, upper connector assembly  112  begins to separate from lower connector assembly  114  by movement of manifold  90 . Upon sufficient movement of manifold  90  with respect to the walls of lower connector assembly  114 , pins  119  are sheared, freeing the upper connector assembly to be withdrawn from the lower connector assembly. It should be noted that in the preferred embodiment, the connector plugs, as well as the fluid and electrical control lines remain sealed within their respective portions of the connector following separation. Also, the foregoing arrangement permits the release of the completion via straight-pull shearing of the pins in conjunction with or without hydraulic assistance. It should also be noted that in the present embodiment, the connector system is pressure biased in an engaged condition because the pressure in control line  56  is generally lower than that present in the well. 
     Turning now to a presently preferred construction of valve  104 , FIGS. 7-12 illustrate presently preferred configurations of a valve for releasing the components of the connector assemblies described above. As shown in FIG. 7, valve  104  is lodged within recess  290  of manifold  90 , and is held within the manifold by a retainer ring  300  secured within a groove  302 . Valve  104  generally includes a spool-type valve member  304 , a seat member  306  surrounding valve member  304 , and a seat housing  308  surrounding a portion of seat member  306 . Both valve member  304  and seat member  306  are movable, as described below, to permit the flow of fluid through the valve, and to open and close the valve selectively for normal and release operations. Moreover, member  308  is also preferably slightly movable within the valve to permit the equalization of forces within the valve assembly. 
     Referring more particularly now to a preferred construction of valve member  304 , member  304  includes an elongated spool  310 . Spool  310  has a seat portion  312  at its lower end, and a valve stop  314  at its upper end. Valve stop  314  is held in place by an annular extension  316 , and a retainer ring  318 . Moreover, valve stop  314  includes flow-through apertures  320  permitting fluid to flow through the stop during operation of the valve. Valve stop  314  is positioned adjacent to an upper end  322  of recess  290  as described below. At its lower side, valve stop  314  abuts a compression spring  324  which serves to bias both the valve member  304  and the seat member  306  toward mutually sealed positions. In the illustrated embodiment, seat portion  312  includes a tapered hard metallic seat surface  326 , as well as a soft elastomeric seat  328  secured in an annular position to provide sealing during a portion of the movement cycle of the valve components. This arrangement provided redundancy in the sealing of the valve member and seat member. 
     Seat member  306  includes an elongated fluid passageway  330  in which spool  310  is disposed. Moreover, along its length, seat member  306  forms an upper extension  332 , an enlarged central section  334 , and a lower actuating extension  336 . Seals are carried by the scat member to seal designated portions of the volumes of the valve. In the illustrated embodiment these seals include an upper T-seal  338  disposed about upper section  332 , and an intermediate T-seal  340  disposed about central section  332 . Upper T-seal  338  seals between the seat member and recess  290 . Intermediate T-seal  340  seals between the seat member and an internal surface of seat housing  306  as described more fully below. Fluid passageways  342  are formed in seat member  306  to place an outer periphery of the seat member in fluid communication with passageway  330 . In the release valve, additional passageways  344  are formed at the base of actuating extension  336 . A lower seat surface  346  is formed to contact hard and soft sealing surfaces  326  and  328  to prevent flow through the value upon closure. 
     Seat housing  308  is positioned intermediate recess  290  and seat member  306 . In the illustrated embodiment, seat housing  308  includes an enlarged bore  348  in which central section  334  of seat member  306  is free to slide. T-seal  340  seals central section  334  in its sliding movement within bore  348 . Seat housing  308  also includes a reduced diameter lower portion  350  surrounding actuating extension  336  of seat member  306 . An internal T-seal  352  is provided in lower portion  350  to seal against the actuating extension. Retaining ring  300  abuts lower portion  350  to maintain the seat housing in place. Below seat housing  308 , within lower recess  353 , a similar internal T-seal  354  is provided for sealing about actuating extension  336 . As described below, in certain applications such as when the valve is used for hydraulic release, seal  354  may be omitted, particularly where sealing between the actuating extension and the lower recess is not required. In the present embodiment no seal  354  is provided in the release valve to permit pressurized fluid access pressure chamber  134 . 
     In the embodiment illustrated in FIG. 7, lower recess  353  is blind, and is configured to receive actuating extension  336  of valve  104 . In the installed position shown in FIG. 7, manifold  90  is fully engaged in lower connector assembly  114 , such that actuating extension  336  contacts a lower end of recess  353  to force seat member  306  into an upper position along seat housing  308 . The upward movement of seat member  306  compresses spring  324  to force valve member  304  into an upper position. A free flow path is thereby defined through control line  56 , apertures  320  in valve stop  314 , inner passageway  330 , and downwardly around seat portion  312  of the valve spool. At the same time, pressure from the passageway  330  of seat member  306  is communicated to the region between central section  334  of the seat member and the lower portion  350  of the seat housing via passageways  342 . Moreover, when the valve is used for hydraulic release the lower volume defined within actuating extension  334  below the spool is in fluid communication with pressure chamber  134  below seat housing  308 . It should be noted that when the valve is mechanically held open, fluid may be permitted to flow in either direction through the valve. 
     Referring now to FIG. 8, for actuation of the valve, and release of the portions of the assembly from one another, pressure is applied at control line  56  such as via an above-ground pressure source. This pressure is transmitted through apertures  320 , through passageway  330 , into actuating extension  336 , and thereby into pressure chamber  134 . As the pressure increases, a parting force is exerted against areas adjacent to pressure chamber  134 . At this time, all valve components are in pressure equilibrium. The valve assembly and manifold  90  are thereby forced away from lower connector assembly  114 , as illustrated in FIG.  9 . Spring  324  will bias the valve member  304  to contact seat member  306 . 
     Following initial parting of the assembly members, valve member  304  will seat against seat member  306  as shown in FIG.  9 . Application of additional pressurized fluid within control line  56  will force the fluid through central passageway  330 , temporarily unseating the spool by relative movement of the valve member  304  and seat member  306  (within the valve recess), resulting in progressive displacement of the manifold in an upward direction under the influence of forces exerted against surfaces adjacent to pressure chamber  134 . As noted above, in the blind arrangement shown in FIGS. 7 through 11, T-seal  354  may be eliminated, due to the free communication of fluid between the actuating extension  336  and pressure chamber  134 . 
     The progressive displacement of the sections of the assembly with respect to one another may proceed under fluid pressure exerted through valve  104  until full disengagement of actuating extension  336  is obtained as shown in FIG.  10 . Thereafter, further application of fluid pressure through the valve continues to unseat valve member  304  from seat member  306 , and seat member  306  from seat housing  308 , to progressively disengage the assembly sections from one another, thereby disconnecting conductors as explained above. Alternatively, once pins  119  or similar controlled release structures are sheared or actuated, the upper and lower connector sections may be separated by relative movement of the completion equipment and the deployment system. Following such full disengagement of the valve from its lower recess, valve  104  will seat as illustrated in FIG.  11 . 
     Following full disengagement of the sections of the assembly, valve  104  serves as a check valve permitting purging of fluids which may infiltrate into control line  56 . In particular, as shown in FIGS. 10 and 11, pressure may be exerted in control line  56  to unseat the valve member and seat member from one another, permitting such purging action. Following reduction in the pressure at control line  56 , spring  324  and pressure surrounding valve member  304 , force the valve member and seat member into seated engagement with one another. It should be noted that in the present embodiment illustrated in the figures, clearance is provided between valve stop  314  and upper end  322  of recess  290 , to permit full seating of the valve and seat member on one another when connector components are separated as shown in FIG.  11 . 
     Various adaptations may be made to valve  104  to permit control lines, instrument lines, and so forth, to communicate between upper and lower portions of the connector assembly, while preventing flooding of such lines upon parting or release. FIG. 12 illustrates one such adaptation incorporated into a valve of the basic structure described above. In particular, rather than the blind cavity described above used to force separation or release of the connector assembly, a fluid passageway or conduit  356  may be formed in communication with the lower fluid volume within actuating extension  336 . In the embodiment shown in FIG. 12, a sealed fitting  358  is provided for transmitting fluid to or from a lower component, such as a packer, slide valve, and so forth. In such arrangements, full engagement of the valve  104  during assembly of the connector system will define a flow path permitting the free exchange of fluid between manifold  90  and the lower component. Upon parting, however, T-seal  354  will prevent the exchange of pressurized fluid between pressure chamber  134  and fluid contained within the valve. It should be noted that in this embodiment, actuating extension  336  does not require fluid passageways  344  (refer to FIG.  7 ), but where such passageways are present, T-seal  354  prevents the exchange of fluids between the control line and pressure chamber  134 . Upon full release of the connector assembly portions, the valve will seat, thereby preventing the flow of well bore fluids, water or other ambient fluids into line  76 . As is described above, pressure applied as line  76  of such valves will, however, permit purging of the feed lines. 
     Also shown in FIG. 13, valve  104  may be adapted for accommodating an integral electrical conductor  360 , such as for a gauge pack or other electrical device. In this adaptation, a central bore  362  is formed through valve member  304 . Conductor  360  is fed through bore  362  and terminates in a bulkhead feed-through electrical connector  364 . In the illustrated embodiment, connector  364  includes a wire plug connection  366 . Such connector arrangements are available in various forms and configurations as will be apparent to those skilled in the art. For instance, one acceptable connector is available commercially from Kemlon, an affiliate of Keystone Engineering Company of Houston, Tex., under the commercial designation K25. Other connector arrangements may include bulkhead connectors configured to prevent flooding of the conduits. Also, coaxial, multi-pin, wet-connectable, and other connectors may be employed to insure continuity of the electrical connection through valve  104 . 
     In a presently preferred configuration, conductor  360  extends through the valve and is in electrical connection with a tubing encapsulated conductor  368 . As in the previous embodiments, valve  104  establishes a flow path upon full engagement of manifold  90  within the assembly. In the case of the valve illustrated in FIG. 12 equipped with an electrical conductor, the electrical conductor may be surrounded by a dialectric fluid medium, such as transformer oil. Alternatively, a sealed contact may be employed to provide a wet-connect arrangement. As the manifold is retracted from the assembly, the electrical connection is interrupted, and the upper line  78  within which the upper conductor  360  is located is closed by operation of the valve. Thereafter, the conductor is electrically isolated by the dialectric fluid within the passageway. As before, the passageway may be purged by exertion of fluid pressure within the passageway to unseat valve member  304  and seat member  306  from one another. 
     It will be understood that the foregoing description is of preferred embodiments of this invention, and that the invention is not limited to the specific form shown. For example, a variety of connector components can be used in constructing the connector; one or more control lines can be added; a variety of control lines, such as fluid control lines, optical fibers, and conductive control lines can be adapted for engagement and disengagement; the fluid control lines can be adapted for delivering fluids, such as corrosion inhibitors etc., to the various components of the completion; and the power cable can be routed through coil tubing or connected along the coil tubing or other deployment systems. Also, a variety of valve configurations may be employed for initial and progressive, controlled release. For example, various seals may be employed in the valve in place of the T-seals discussed above, such as metal-to-metal seals, cup seals, V packing, poly-seals and so forth. Similarly, data or power signals may be exchanged with a component of the completion via internal connections other than the plug arrangement and feed through valve structure described above. These and other modifications may be made in the design and arrangement of the elements without departing from the scope of the invention as expressed in the appended claims.