Patent Document

CROSS-REFERENCE TO RELATED APPLICATION 
       [0001]    This application claims benefit of U.S. Provisional Patent Application Ser. No. 61/221,843, entitled “Apparatus, System and Method for Communicating While Logging With Wired Drill Pipe,” filed Jun. 30, 2009, which is herein incorporated by reference. 
     
    
     BACKGROUND OF INVENTION 
       [0002]    Well logging instruments are devices configured to move through a wellbore drilled through subsurface rock formations. The devices include one or more tools and other devices that measure various properties of the subsurface formations and/or perform certain mechanical acts on the formations. Such acts include drilling or percussively obtaining samples of the rock formations, and withdrawing samples of connate fluid from the rock formations. Measurements of the properties of the rock formations may be recorded with respect to the instrument axial position (depth) within the wellbore as the instrument is moved along the wellbore. Such recording is referred to as “well logging.” 
         [0003]    Well logging instruments can be conveyed along the wellbore by extending and withdrawing an armored electrical cable (“wireline”), to which the instruments are coupled at the end thereof. Extending and withdrawing the wireline may be performed using a winch or similar spooling device. However, such conveyance relies on gravity to move the instruments into the wellbore, which can only be used on substantially vertical wellbores. Wellbores deviating from vertical require additional force to move the well logging instruments through the wellbore. 
         [0004]    One conveyance technique for conveying wireline instruments into a non-vertical wellbore includes coupling the wireline instruments to the end of coiled tubing having a wireline disposed therein. The wireline instruments are extended into and withdrawn from the wellbore by extending and retracting the coiled tubing, respectively. However, the use of coiled tubing with wireline instruments is costly and is inherently limited by the amount of pushing force the coiled tubing is capable of providing to assist the movement of the wireline instruments through the wellbore. As a result, the use of coiled tubing is typically problematic in extended reach wells. 
         [0005]    Another well logging instrument conveyance technique includes coupling wireline configurable well logging instruments to the end of a drill pipe or similar threadably coupled pipe string. As the pipe string is extended into the wellbore, the wireline is extended by operating a conventional winch while the pipe string is being conveyed into the wellbore. However, this conveyance technique is frequently unreliable as the wireline is positioned in the annulus and subject to crushing, splicing, or other damage. For example, the wireline may become pinched between the drill pipe and the casing or wellbore. Another drawback to using drill pipe to convey the well logging instruments is that the cable disposed outside the pipe disturbs the operation of the sealing equipment and makes it difficult to seal the drill pipe to maintain fluid pressure. 
         [0006]    Additionally, the well logging instruments may be positioned at the end of a drill pipe without the use of a wireline cable. In such circumstances, each well logging instrument is provided with a battery and memory to store the acquired data. As a result, the well logging instruments cannot communicate with the surface while downhole. Therefore, the data acquired, that may be critical to efficiently drilling the wellbore, cannot be analyzed at the surface until the wireline instruments return to the surface. Without any communication with the surface, surface operators cannot be certain the instruments are operating correctly and cannot modify the operation of the instruments in view of the data acquired. 
         [0007]    Recently, a type of drill pipe has been developed that includes a signal communication channel within the structure of the pipe, which serves to protect the communication channel and assist in the movement thereof. Such drill pipe, known as wired drill pipe (“WDP”), has a signal coupler at each end thereof that is coupled to the signal communication channel within. When the signal coupler of one wired drill pipe is placed in proximity or in contact with the signal coupler of another wired drill pipe, for example when the two pipe ends are coupled together, signals may be transmitted between the signal couplers. These connections provide a contiguous signal communication channel from one end of a series of wired drill pipes to the other. The use of wired drill pipes has provided increased signal telemetry speed for use with “logging while drilling” (“LWD”) instruments over conventional LWD signal telemetry, which typically is performed by mud pressure modulation or by very low frequency electromagnetic signal transmission. 
         [0008]    At the surface, while drilling, a surface receiver sub is usually connected to the wired drill pipe (or wired drill string) to receive data from downhole and relay that data to a surface computer system, either by a hard wired connection or wirelessly. When one stand of pipe is drilled, a new stand needs to be connected. To connect a new stand, the surface receiver sub needs to be disconnected from the drill string. With current receiver subs and methods, disconnecting the receiver sub may take several minutes to complete. The same is true when reconnecting the receiver sub onto the newly attached pipe stand. As a result the communications between downhole tools and the surface system is disconnected, usually for at least few minutes, until the new stand is connected to the wired drill string and to the surface receiver sub. During this time, information packets that may have been traveling through the pipe and to the surface receiver sub may be lost. 
         [0009]    This process happens in reverse when tripping out of the wellbore. While tripping out, the surface receiver sub is not present and the drill string is lifted out of the wellbore by the elevators and lifting bales. As each stand of drill pipe is tripped out of the wellbore, the rest of the wired drill string is secured on the rig floor by slips while the stand is disconnected from the wired drill string and secured on the rack. The elevators and the lifting bales are then lowered to pickup the next stand. During tripping in the wellbore, there is typically no communication between the downhole tools or other components of the WDP network and the surface system. There must be a receiver communicatively connected to the drill string, near or at the surface, in order to transmit data to the surface system. 
         [0010]    As described above, during drilling, the transmission of data is done using a receiver sub that sits below the top-drive which can send the data onwards to the surface system. Since the surface receiver sub is generally threaded to the wired drill string in a top-drive, it is a slow process. The time required to thread in the receiver sub during drilling is acceptable since it takes a significantly longer time to drill a stand as compared to the time to reconnect the receiver sub after communication is disconnected. However, during logging while tripping with “wireline logging” (“WL”) tools using WDP, the tripping time is much faster than the drilling time. Current devices and methods do not afford time to reconnect the receiver sub while tripping the WDP. It is beneficial to have the receiver sub attached to the drill WDP for the maximum amount of time so long as it does not interfere with the attachment of a new pipe stand. Therefore, to effectively use WL instruments with wired drill pipe, an apparatus, system and method for efficiently attaching and detaching a surface receiver sub is needed. 
     
    
     
       BRIEF DESCRIPTION OF THE DRAWINGS 
         [0011]      FIG. 1  illustrates a drill rig having a drill string on which embodiments of the present inventions may be used. 
           [0012]      FIG. 2A  Illustrates a cross-sectional view of one embodiment of a wired drill pipe. 
           [0013]      FIG. 2B  illustrates a top view of the wired drill pipe of  FIG. 2A . 
           [0014]      FIG. 2C  illustrates a further embodiment, in cross-section, of a wired drill pipe. 
           [0015]      FIG. 2D  illustrates a top view of the wired drill pipe of  FIG. 2C . 
           [0016]      FIG. 3A  illustrates a top view of a communication system for transmitting data to and/or from a drill string to a surface component according to one embodiment of the inventions described herein. 
           [0017]      FIG. 3B  illustrates a side view of the communication system of  FIG. 3A . 
           [0018]      FIG. 3C  illustrates a cross sectional view of the communication system of  FIGS. 3A and 3B  with the tripping sub positioned within the pipe end of  FIG. 2C . 
           [0019]      FIG. 4A  illustrates a tripping sub being positioned in the pipe end of  FIG. 2A  according to one embodiment of the inventions described herein. 
           [0020]      FIG. 4B  illustrates one embodiment of a latching method for the tripping sub of  FIG. 4A . 
           [0021]      FIG. 4C  illustrates the tripping sub of  FIGS. 4A and 4B  with an additional locating feature according to one embodiment of the inventions described herein. 
       
    
    
     DETAILED DESCRIPTION 
       [0022]    Generally, embodiments of the inventions relate to a system and method for communicating with a wellbore instrument or a “string” of such instruments in a wellbore using a wired pipe string for conveyance and signal communication. The wired pipe string may be assembled and disassembled in segments to effect conveyance through a wellbore. While embodiments of the present inventions are described as used with tools commonly conveyed on a wireline (“wireline tools”), embodiments may be implemented with any other type of downhole tools, such as LWD tools. The description provided below relates to embodiments of the inventions, and none of the embodiments are meant to limit the inventions. The inventions should be provided their broadest, reasonable meaning as defined by the claims. 
         [0023]    In  FIG. 1 , a drilling rig  24 , or similar lifting device for conveying drill pipe, moves a wired pipe string  20  within a wellbore  18  that has been drilled through subsurface rock formations, shown generally at  11 . The wired pipe string  20  may be extended into the wellbore  18  by threadedly coupling together the inserting end and the receiving end of a number of segments (“joints”)  22  of wired drill pipe. 
         [0024]    The wired pipe string  20  may include one, an assembly, or a “string” of wellbore instruments at a lower end thereof. In the present example, the wellbore instrument string may include well logging instruments  13  coupled to a lower end thereof. As used in the present description, the term “well logging instruments” or a string of such instruments means one or more wireline configurable well logging instruments that are capable of being conveyed through a wellbore using armored electrical cable (“wireline”), logging while drilling (“LWD”) tools, measure while drilling (“MWD”) tools, formation evaluation tools, formation sampling tools, and/or other tools capable of measuring a characteristic of the formation. Wireline configurable well logging instruments are distinguishable from LWD instruments, which are configurable to be used during drilling operations and form part of the pipe string itself. While generally referred to as the well logging instrument  13 , the well logging instrument  13  may include one, an assembly, or a string of wireline configurable logging instruments. 
         [0025]    Several of the components disposed proximate the drilling unit  24  may be used to operate components of the system. These components will be explained with respect to their uses in drilling the wellbore to better enable understanding of the inventions. The wired pipe string  20  may be used to turn and axially urge a drill bit into the bottom of the wellbore  18  to increase its length (depth). During drilling of the wellbore  18 , a pump  32  lifts drilling fluid (“mud”)  30  from a tank  28  or pit and discharges the mud  30  under pressure through a standpipe  34  and flexible conduit  35  or hose, through a top drive  26  and into an interior passage (not shown separately in  FIG. 1 ) inside the pipe string  20 . The mud  30  exits the drill string  20  through courses or nozzles (not shown separately) in the drill bit, where it then cools and lubricates the drill bit and lifts drill cuttings generated by the drill bit to the Earth&#39;s surface. 
         [0026]    When the wellbore  18  has been drilled to a selected depth, the pipe string  20  may be withdrawn from the wellbore  18 . An adapter sub  12  and the well logging instrument  13  may then be coupled to the end of the pipe string  20 , if not previously installed. The pipe string  20  may then be reinserted into the wellbore  18  so that the well logging instrument  13  may be moved through, for example, an inclined portion  18 A of the wellbore  18 , which would be inaccessible using armored electrical cable (“wireline”) to move the well logging instrument  13 . The well logging instrument  13  may be positioned on the pipe string  20  in other manners, such as by pumping the well logging instrument  13  down the inner bore of the pipe string  20  or otherwise moving the well logging instrument  13  down the pipe string  20  while the pipe string  20  is within the wellbore  18 . 
         [0027]    During well logging operations, the pump  32  may be operated to provide fluid flow to operate one or more turbines (not shown in  FIG. 1 ) in the well logging instrument  13  to provide power to operate certain devices in the well logging instrument  13 . However, when tripping in or out of the wellbore  18 , it is generally infeasible to provide fluid flow. As a result, power may be provided to the well logging instrument  13  in other ways. For example, batteries may be used. In one embodiment, the batteries may be rechargeable batteries that may be recharged by turbine(s) during fluid flow. The batteries may be positioned within the drill collar of the tool or in a separate drill collar. Other known manners of powering the well logging instrument  13  may be used as well. 
         [0028]    As seen in  FIGS. 2A-D , wired drill pipe is structurally similar to ordinary drill pipe. The wired pipe string  20  may comprise pipe joints communicatively coupled together such that data may be transmitted across each pipe joint. For example, wired drill pipe may include a cable, either partially or fully embedded within the structure of the pipe, associated with each pipe joint that serves as a signal communication channel and possibly for electrical power delivery. The cable may be any type of cable capable of transmitting data and/or signals, such as an electrically conductive wire, a coaxial cable, an optical fiber, or the like. Wired drill pipe typically includes some form of communication element connected to the signal communication channel to communicate signals between adjacent pipe joints when the pipe joints are coupled end to end as shown in  FIG. 1 . Examples of communication elements include inductive couplers, non-toroidal inductive couplers, flux couplers, direct connect couplers, or any component for transmitting data across tool joints. In an embodiment, the wired pipe string  20  may be similar to the wired pipe string described in U.S. Pat. No. 7,413,021, filed by Madhavan, et al., and assigned to the assignee of the present invention, or U.S. Pat. No. 6,641,434 issued to Boyle et al., and assigned to the assignee of the present invention. 
         [0029]    The embodiment shown in  FIG. 2A  has the receiving end of a pipe (pipe end  200 ), in cross-section, having an inner shoulder  203 , threaded section  204 , outer shoulder  205 , and a communication element  201  embedded within the inner shoulder  203 . The threaded section  204  as shown may generally resemble the surface of a tapered cylinder, having threads disposed thereon, which extends from the surface of the inner shoulder  203  to the surface of the outer shoulder  205 . The surfaces of the inner shoulder  203  and outer shoulder  205  may be generally parallel to one another and generally perpendicular to a central axis of the pipe end  200 . The communication element  201  in this embodiment is a ring of electrically conductive material positioned around the inner bore  206  of the pipe end  200 , as shown in  FIG. 2B . The communication element  201  may have a portion exposed at a surface of the inner shoulder  203 . Coupled to the communication element  201  is a signal communication channel  202  embedded within the pipe end  200 . The communication element  201  may be made of an electrically conductive material, an inductive coil, fiber optic array, or any other element capable of communicating signals. 
         [0030]    In  FIG. 2C , a communication element  207 , which is similar in shape and function to the communication element  201  of  FIGS. 2A and 2B , is embedded within the threaded section  204  of the pipe end  200  rather than in the inner shoulder  203 . The communication element  207  may have a portion which may be exposed at a surface of the threaded section  204 . The communication element  207  is also connected to a signal communication channel  202 .  FIG. 2D  shows a top view of the pipe end  200  to further illustrate how the communication element  207  is positioned.  FIGS. 2A-D  are presented as examples of a wired drill pipe, and should not be considered limiting of the inventions. Embodiments of the present inventions can be used with other communication or telemetry systems, including a combination of telemetry systems, such as a combination of wired drill pipe, mud pulse telemetry, electronic pulse telemetry, acoustic telemetry, or the like. 
         [0031]    Referring back to  FIG. 1 , signals detected by various devices, non-limiting examples of which may include an induction resistivity instrument  16 , a gamma ray sensor  14 , and a formation fluid sampling device  10  (which may include a fluid pressure sensor), of the well logging instrument  13  may be transmitted toward the Earth&#39;s surface along the wired pipe string  20 . The signals transmitted by the well logging instrument  13  may be transmitted to a receiver sub (not shown in  FIG. 1 ), embodiments of which are described below. The receiver sub may be configured to receive signals from the well logging instrument  13  and transmit them to a surface computer or component to be recorded and/or analyzed. Signals may be transmitted during tripping of the pipe string  20 , while the pipe string  20  is stationary, during drilling operations, or during run-in operations. 
         [0032]    When tripping in and out of the wellbore  18  or performing another process where drill pipe is being added, removed, or disconnected from the wired pipe string  20 , it may be beneficial to have an apparatus and system for communicating from the wired drill pipe string  20  to a surface computer or other component to receive, analyze, and/or transmit data. One embodiment of a wired drill pipe communication system  300  for connection to the wired drill pipe string  20  is shown in  FIGS. 3A-C . The system  300  is depicted in  FIGS. 3A and 3B  from its top and side views, respectively. 
         [0033]      FIGS. 3A and 3B  show a communication sub, herein after tripping sub  310 , that may be positioned in, secured to, and/or attached to a motion system as part of the communication system  300 . The motion system may be for positioning and attaching the tripping sub  310  relative to the receiving end (end  330 ) of a pipe  335 . In one embodiment, the motion system may include vertical adjustment arms  305  and lateral adjustment arms  301  which may be connected to and/or secured to top drive elevators and lifting bales  325 . For example, a clamp  320  may be used to secure the adjustment arms  301 ,  305  to the elevators and lifting bales  325 . The clamp  320  and adjustment arms  301 ,  305  may move with the top drive lifting bales  325 . The tripping sub  310  may be attached to the vertical adjustment arms  305 . The adjustment arms  301 ,  305  may be adjusted to move the tripping sub  310  vertically and/or laterally. The tripping sub  310  may be positioned by the adjustment arms  301 ,  305  into the end  330  of the pipe  335 . The end  330  of the pipe  335  may be, for example, of similar construction to those shown in  FIGS. 2A-D . The adjustment arms  301 ,  305  may be one of a cylinder, linear actuator, drive screw, or other such device configured to vertically and/or laterally position the tripping sub  310 . The adjustment arms  301  and  305  may be adjusted manually or automatically. The adjustment arms  301 ,  305  may be hydraulic or electrically driven and may be controlled from a remote location or by an operator standing adjacent the communication system  300 . The adjustment arms  301 ,  305  may be equipped with sensors to determine a position of the adjustment arms and/or the tripping sub  310  with respect to the end  330  of the pipe  335 . The adjustment arms  301 ,  305  may also contain force and/or torque sensors to determine, change, and/or limit the amount of force used to position the tripping sub  310  into the end  330  of the pipe  335 . The tripping sub  310  should be placed with an adequate amount of force so that communication elements (not shown in  FIGS. 3A and 3B ) embedded within the pipe sections  22  and tripping sub  310  are in close proximity or in contact to allow the communication of signals to one another. 
         [0034]    In one embodiment, the adjustment arms  301 ,  305  may be provided with a communications module  340  comprising one or more of a camera, a wired communication port, a wireless antenna, a global positioning satellite/receiver, and components for transferring data, images, and information related to the position of the tripping sub  310  and/or the adjustment arms  301 ,  305 . The force and/or the torque sensors for the adjustment arms  301 ,  305  may be incorporated into and/or positioned within the communications module  340 . The communications module  340  may communicate bi-directionally with a processor, surface computer or component for transmitting controls related to the operation of the adjustment arms  301 ,  305 . 
         [0035]    The tripping sub  310  may have sensors for determining and/or measuring forces applied to it and/or its location. For example, the sensors may be torque or positional sensors to ensure proper alignment and securement of the tripping sub  310  in the pipe  335 . The sensors may aid in aligning the tripping sub  310  with the pipe  335  without damaging the tripping sub  310  or the pipe  335 . In one embodiment, insertion of the tripping sub  310  into the pipe  335  may automatically cease upon proper verified communication with the pipe  335 . In an embodiment comprising an automated process, the tripping sub  310  may transmit a signal to the adjustment arms  301 ,  305  upon communication with the pipe  335 . 
         [0036]    The tripping sub  310  may comprise a coupler head  311 , a neck  312 , and a body  313 . The coupler head  311 , neck  312 , and body  313  may be integrally formed or may be separate components communicatively coupled. In either embodiment, the coupler head  311  may comprise a communication element for communicating with the pipe  335  and sensors for position and/or force. The neck  312  may comprise sensors for position and force as well as a communication device for transmission of data to a surface computer, processor, or other component located locally or remotely with respect to the rig. It should be appreciated that this is merely one example of the construction of the tripping sub  310  and other configurations are possible. 
         [0037]      FIG. 3C  depicts the communication system  300  in cross-section with the tripping sub  310  positioned within the pipe end  200  of  FIG. 2C . In one embodiment, the coupler head  311  may be substantially similar in shape to the threaded section  204  of the pipe end  200 . For example, the coupler head  311  may be in the shape of a tapered cylinder with one end being of a similar diameter to the diameter of the inner shoulder  203  and having a taper angle matching that of the threaded section  204  of the pipe end  200 . The coupler head  311  may extend from the inner shoulder  203  of the pipe end  200  and may terminate before the outer shoulder  205 , at the outer shoulder  205 , or beyond the outer shoulder  205 . The coupler head  311  may have contours similar in shape to the threads of the threaded section  204  to allow for better placement and engagement with the pipe end  200  while not having to thread the tripping sub  310  into the pipe end  200 . The shaping of the coupler head  311  as described above may increase the efficiency of placement of the tripping sub  310  into the pipe end  200 . By having the coupler head  311  formed in a similar shape to the threaded section  204  axial alignment of the tripping sub  310  into the pipe end  200  may be more readily attained when the surfaces of the coupler head  311  and threaded section  204  are in contact along their entire perimeter. In one embodiment, the tapered surface of the coupler head  311  may force the tripping sub  310  closer toward the center of the pipe end  200  when contacted by the tapered surface of the threaded section  204 . 
         [0038]    The tripping sub  310  may further contain a battery  314 , housed within the body  313 , and a wireless transmitter  315 , housed in the coupler head  311 , which can transfer signals received from the well logging instrument  13  to a surface computer or processor or other component on the rig. Connecting the battery  314  and wireless transmitter  315  may be a wire  317  which may provide power from the battery  314  to the wireless transmitter  315 . The battery  314  and wireless transmitter  315  may be housed in the body  313 , neck  312 , or coupler head  311  together or separately depending on the size and shape of the components used. 
         [0039]    Embedded within the coupler head  311  may be a communication element  316  which may be used to communicate with the communication element  207  of the pipe end  200 . The communication element  316  is positioned within the coupler head  311  in such a way that when the tripping sub  310  is properly positioned into the pipe end  200  the communication element  316  of the tripping sub  310  and the communication element  207  of the pipe end  200  are in close proximity or in contact with one another. The communication element  316  may be oversized, compared to the communication element  207 , in a direction parallel to the tapered surface of the coupler head  311 . Over sizing the communication element  316  may assist in establishing communicative contact with the communication element  207  if the tripping sub  310  is not fully inserted or properly aligned with the pipe end  200 . 
         [0040]    Connecting the communication element  316  to the wireless transmitter  315  may be a wire  318 . The wireless transmitter  315  may be replaced with a wired connection, and the battery  314  may be replaced with a power chord or similar powering device. The neck  312  of the tripping sub  310  may be constructed in a way such that the body  313  is in contact with or proximate to the outer shoulder  205  of the pipe end  200  when the tripping sub  310  is properly positioned. An advantage of having the neck  312  be of a length such that the body does not contact the outer shoulder  205  allows for adequate pressure to be applied to the coupler head  311 , before the body  313  contacts the outer shoulder  205 , so as to assure proper placement of the coupler head  311  and communication element  316 . 
         [0041]    The adjustment arms  301 ,  305  may provide adequate vertical and/or lateral forces while the coupler head  311  is positioned within the pipe end  200  so the tripping sub  310  does not become removed from the pipe end  200 , thereby breaking communications between the communication element  207  of the pipe end  200  and the communication element  316  of the tripping sub  310 . 
         [0042]    In another embodiment, the tripping sub  310  may be pressure or friction fit into the pipe  335 . For example, the coupler head  311  may be adjustable from a first diameter to a second diameter, wherein the second diameter is substantially similar to the diameter of the threaded section  204  of the pipe end  200 . The coupler head  311  may be constructed of a material that is deformable and has elasticity so that when inserted into the pipe end  200  the coupler head  311  may assume a shape and size similar to that of the threaded section  204 . In another embodiment, the coupler head  311  may have a partially threaded exterior in order to provide an additional mode of engagement with the pipe end  200 . In another embodiment, the tripping sub  310  may have a connection, such as for example a box end connection, which only requires a partial rotation of the tripping sub  310  to provide coupling engagement with the pipe end  200 . In another embodiment, the tripping sub  310  may be held in the pipe end  200  by its own weight. 
         [0043]    The tripping sub  310  may be made of a material softer than the pipe  335 . For example, the tripping sub  310  may be made of a material, such as rubber, aluminum, brass, chrome, or other materials. The material for the tripping sub  310  may be selected to eliminate any damage to the threads of the pipe  335  due to any misalignment during connection. The material of the tripping sub  310  may also be one that is resistant to corrosion caused by the caustic materials used during drilling, such as drilling “mud”, oil, or other chemicals. 
         [0044]    In use, the well logging instrument  13  and/or other tools are connected and deployed in the well using the wired drill string  20 . The well logging instrument  13  may log the wellbore  18  while tripping in and/or out of the wellbore  18 . When the drill string  20  is tripped into a position in which the well logging instrument  13  is to begin logging the wellbore  18 , the pipe  335  may be positioned in slips and held by the lifting bales  325  at the end  330  of the pipe  335 . The tripping sub  310  may be positioned in the end  330  of the pipe  335  to provide communication between the pipe  335 , the wired drill string  20  and a surface component, such as a surface processor or computer. Upon connection with the pipe  335 , the surface system may send commands and receive data to and from the well logging instrument  13  and/or other downhole components. At the same time, the top drive elevator and lifting bales  325  can start tripping out of the wellbore  18 . The system  300  can continue to collect data and send commands to and/or from the well logging instrument  13  until the pipe  335  is disconnected from the wired drill string  20 . Then, the tripping sub  310  (or another tripping sub  310 ) may be positioned in a subsequent pipe and the process may be repeated. 
         [0045]    Referring now to  FIGS. 4A-C , embodiments of a tripping sub, in cross-section, and method for quick connection are shown. In  FIG. 4A  a tripping sub  400  is shown disposed in pipe end  200  in a pre-latched position. The tripping sub  400  generally includes a body  407 , neck  408 , coupler head  409 , communication element  410 , latching arms  411 , and arm couplers  412 . In the embodiment shown, the latching arms  411  are extended in an open position allowing easy placement or removal of the tripping sub  400  into or out of the pipe end  200 . The arm couplers  412  may be any coupler that allows axial rotation of the latching arms  411 . This can include, but is not limited to, bolts, screws, shafts, etc. The arm couplers  412  couple latching arms  411  to the body  407 . The neck  408  is coupled to the body and may be formed of, for example, a hollow pipe, spring, or solid pipe with an internal communication channel  416  to allow communication between the communication element  410  and a wireless transmitter  417 . The wireless transmitter  417 , depending on the size and shape of the device, may be positioned within the body  407 , neck  408 , or coupler head  409 . The wireless transmitter  417  may be replaced by a wired connection. The wired or wireless connection allows data communication with a surface component, such as a surface processor or computer, and the tripping sub  400 . An exemplary embodiment for the neck  408  is a spring which provides flexibility and would help to ensure proper placement and coupling pressure between the inner pipe shoulder  203  and the coupler head  409 . This ensures an adequate connection between communication element  201  and communication element  410 . 
         [0046]    The communication element  410  is positioned within the coupler head  409  in such a way that when the tripping sub  400  is properly positioned into the pipe end  200  the communication element  410  of the tripping sub  400  and the communication element  201  of the pipe end  200  are in close proximity or in contact with one another. The communication element  410  may be oversized, compared to the communication element  201 , in a direction parallel to the end surface of the coupler head  409 . Over sizing the communication element  410  may assist in establishing communicative contact with the communication element  201  if the tripping sub  400  is not fully inserted or properly aligned with the pipe end  200 . 
         [0047]    Placement of the tripping sub  400  into the pipe end may be accomplished in several ways, such as for example through an automated process or manually. The tripping sub  400  may have sensors for determining and/or measuring forces applied to it and/or its location. The sensors may aid in aligning the tripping sub  400  with the pipe end  200  without damaging the tripping sub  400  or the pipe end  200 . In one embodiment, insertion of the tripping sub  400  into the pipe end  200  may automatically cease upon proper verified communication between the communication element  201  of the pipe end  200  and the communication element  410  of the tripping sub  400 . For example, an indicator, such as a light (not shown) attached to the tripping sub  400 , may signal when proper placement or communication with the pipe end  200  has been achieved. 
         [0048]    In one embodiment, the coupler head  409  may be substantially similar in shape to the threaded section  204  of the pipe end  200 . For example, the coupler head  409  may be in the shape of a tapered cylinder with one end being of a similar diameter to the diameter of the inner shoulder  203  and having a taper angle matching that of the threaded section  204  of the pipe end  200 . The coupler head  409  may extend from the inner shoulder  203  of the pipe end  200  and may terminate before the outer shoulder  205 , at the outer shoulder  205 , or beyond the outer shoulder  205 . The coupler head  409  may have contours similar in shape to the threads of the threaded section  204  to allow for better placement and engagement with the pipe end  200  while not having to thread the tripping sub  400  into the pipe end  200 . The shaping of the coupler head  409  as described above may increase the efficiency of placement of the tripping sub  400  into the pipe end  200 . By having the coupler head  409  formed in a similar shape to the threaded section  204  axial alignment of the tripping sub  400  into the pipe end  200  may be more readily attained when the surfaces of the coupler head  409  and threaded section  204  are in contact along their entire perimeter. In one embodiment, the tapered surface of the coupler head  409  may force the tripping sub  400  closer toward the center of the pipe end  200  when contacted by the tapered surface of the threaded section  204 . The coupler head  409  may be made of a material that is softer than the material of the pipe end  200  in order to ensure that the threads in the threaded section  204  are not damaged during placement of the tripping sub  400 . The material of the tripping sub  400  may also be resistive to the corrosive materials and chemicals which it may be in contact with. 
         [0049]      FIG. 4B  depicts the latching arms  411  in a latched position. In the embodiment shown, the latching arms  411  may rotate about the arm couplers  412  into a position to secure the tripping sub  400  to the pipe end  200  while the tripping sub  400  is positioned within the pipe end  200 . In one embodiment, the latching arms  411  may be a bar or sheet of material and have portions  413  that match the contour of an outer diameter  415  of the pipe end  200 . In another embodiment, the latching arms  411  may also match a perimeter contour of the pipe end  200  to provide a larger surface for contacting the surface of the outer diameter  415  of the pipe end  200 . Coupled between the arm couplers  412 , body  407 , and latching arms  411  may be a latch mechanism (not shown) which may be used to hold the arms in a generally open ( FIG. 4A ) or generally closed ( FIG. 4B ) position. The latching mechanism may be used to resist the axial rotation of latching arms  411  about arm couplers  412  in order to properly secure the tripping sub  400  to the pipe end  200 . The latching mechanism may include one of a lock, brake, motor, linear actuator, spring, or any other type of mechanism that may selectively resist rotation, and/or combinations thereof. The latching arms  411  being latched in a closed position ( FIG. 4B ) allow for the portions  413  of the latching arms  411  to resist the tripping sub  400  from being decoupled from the pipe end  200  by creating a resistive force between portions  413  and the outer diameter  415  of the pipe end  200 . 
         [0050]    Other forms of quick connection between the tripping sub  400  and pipe end  200  are possible. In one embodiment, the tripping sub  400  may be pressure or friction fit into the pipe end  200 . For example, the coupler head  409  may be adjustable from a first diameter to a second diameter, wherein the second diameter is substantially similar to the diameter of the threaded section  204  of the pipe end  200 . The coupler head  409  may be constructed of a material that is deformable and has elasticity so that when inserted into the pipe end  200  the coupler head  409  may assume a shape and size similar to that of the threaded section  204 . In another embodiment, the coupler head  409  may have a partially threaded exterior in order to provide an additional mode of engagement with the pipe end  200 . In another embodiment, the tripping sub  400  may have a connection, such as for example a box end connection, which only requires a partial rotation of the tripping sub  400  to provide coupling engagement with the pipe end  200 . In another embodiment, the tripping sub  400  may be held in the pipe end  200  by its own weight. 
         [0051]    While the tripping sub  400  is in place, the communication element  201  and communication element  410  are communicatively coupled by proximity or by contact. Well logging instrument  13  may communicate through the wired drill string  20  to the tripping sub  400  while the communication element  201  and communication element  410  are communicatively coupled. 
         [0052]    The tripping sub  400  may be attached and detached as described above by a person or through an automated process. The embodiments described above allow for efficient removal and placement of the tripping sub  400  which allows data from well logging instrument  13  to be collected more often and at greater length. The tripping sub  400  may be quickly coupled during downtime in a well drilling process. Normally this would not be feasible as other methods can take several minutes to position and attach a data transmission device. 
         [0053]      FIG. 4C  shows an embodiment where the coupler head  409  of tripping sub  400  contains an additional locating feature  414  that uses the inner bore  205  to further assist in properly aligning the tripping sub  400  into the pipe end  200 . The additional locating feature  414  may be of any size and shape which assists in aligning the tripping sub  400  with the pipe end  200 . The shape of the additional locating feature  414  may be, for example, cylindrical, conical, or combinations and sections thereof. 
         [0054]    While the invention has been described with respect to a limited number of embodiments, those skilled in the art, having benefit of this disclosure, will appreciate that other embodiments can be devised which do not depart from the scope of the invention as disclosed herein. Accordingly, the scope of the invention should be limited only by the attached claims.

Technology Category: 0