Patent Abstract:
A production assembly and method for controlling production from production tubing supported by a tubing hanger in a well including a wellhead. The assembly includes a function spool engaged with the wellhead and a tree engaged with the function spool. The tubing hanger is landable in the tree bore such that the production tubing is supported in the well by the tree. A function mandrel separate from the tubing hanger is engaged with the production tubing and positionable inside the function spool bore. The function mandrel includes a passage connected to a line extending into the well that is connectable with a port in the function spool such that communication with a downhole component through the line is allowable from outside the function spool.

Full Description:
STATEMENT REGARDING FEDERALLY SPONSORED RESEARCH OR DEVELOPMENT 
     Not Applicable. 
     BACKGROUND 
     A well capable of producing oil or gas will typically have a well structure to provide support for the borehole and isolation capabilities for different formations. Typically, the well structure includes an outer structure such as a conductor housing at the surface that is secured to conductor pipe that extends a short depth into the well. A wellhead housing is landed in the conductor housing with an outer or first string of casing extending from the wellhead and through the conductor to a deeper depth into the well. Depending on the particular conditions of the geological strata above the target zone (typically, either an oil or gas producing zone or a fluid injection zone), one or more additional casing strings will extend through the outer string of casing to increasing depths until the well is cased to its final depth. Each string of casing is supported at the upper end by a casing hanger that lands in and is supported by the wellhead housing, each set above the previous one. Between each casing hanger and the wellhead housing, a casing hanger seal assembly is set to isolate each annular space between strings of casing. The last, and innermost, string of casing extends into the well to the final depth and is referred to as the production casing. The strings of casing between the outer casing and the production casing are typically referred to as intermediate casing strings. 
     When drilling and running strings of casing in the well, it is critical that the operator maintain pressure control of the well. This is accomplished by establishing a column of fluid with predetermined fluid density inside the well that is circulated down into the well through the inside of the drill string and back up the annulus around the drill string to the surface. This column of density-controlled fluid balances the downhole pressure in the well. A blowout preventer system (BOP) is also used to as a safety system to ensure that the operator maintains pressure control of the well. The BOP is located above the wellhead housing and is capable of shutting in the pressure of the well, such as in an emergency pressure control situation. 
     After drilling and installation of the casing strings, the well is completed for production by installing a string of production tubing that extends to the producing zone within the production casing. The production tubing is supported by a tubing hanger assembly that lands and locks above the production casing hanger. Perforations are made in the production casing to allow fluids to flow from the formation into the productions casing at the producing zone. At some point above the producing zone, a packer seals the space between the production casing and the production tubing to ensure that the well fluids flow through the production tubing to the surface. 
     Various arrangements of production control valves are arranged at the wellhead in an assembly generally known as a tree, which is generally either a vertical tree or a horizontal tree. A horizontal tree arranges the production control valves offset from the production tubing and one type of horizontal tree is a Spool Tree™ shown and described in U.S. Pat. No. 5,544,707, hereby incorporated herein by reference for all purposes. A horizontal tree locks and seals onto the wellhead housing but instead of being located in the wellhead, the tubing hanger locks and seals in the tree bore itself. After the tree is installed, the tubing string and tubing hanger are run into the tree using a tubing hanger running tool (THRT) and a locking mechanism locks the tubing hanger in place in the tree. The production port extends through the tubing hanger and seals prevent fluid leakage as production fluid flows into the corresponding production port in the tree. 
     The tubing hanger typically has a plurality of auxiliary passages that surround the vertical bore associated with the production tubing. The auxiliary passages provide penetration access through the tubing hanger from outside the tree for hydraulic, optical, and electrical components located downhole. Electrical, optical, and hydraulic lines extend downhole alongside the tubing to control and/or power downhole valves such as a surface-controlled subsurface safety valve (SCSSV), temperature sensors, electric submersible pumps (ESP), downhole processors, and the like, as well as possibly provide for chemical reagent injection. Other types of lines than those listed may also be extended downhole. As the tubing hanger is landed and set in the tree, the auxiliary passages in the tubing hanger typically wet mate with auxiliary connectors located in the tree itself that may lead to a control unit mounted to the tree assembly. 
     A disadvantage of the conventional type of subsea wellhead assembly is that the tubing hanger must be large enough to house the number of passages extending through it. In addition to housing the passages, the tubing hanger requires a certain amount of structural integrity to support the production tubing. Thus there are only so many auxiliary passages that may be included in a given size tubing hanger before the tubing hanger needs to be enlarged. A large diameter tubing hanger also requires a large diameter drilling riser and BOP through which the tubing hanger must be run prior to installing the tree. Additionally, if the tubing hanger is made longer, the tree must also be lengthened, resulting in additional costs and weight for both items. 
     Another disadvantage of the auxiliary passages is that different wells may require different functions. Thus, trees must be “customized” to meet the needs of the particular well. Whereas certain downhole functionality may be common among many wells, other types of functionality may be more optional. Building a “one-size-fits-all” tubing hanger/tree thus would be inefficient because unwanted functionality built into the tree/tubing hanger adds unnecessary size, weight, and cost to the completion. Manufacturing costs alone would cause inefficiencies because of the added complexity and labor of manufacturing auxiliary ports into a solid tree body. 
     Another concern is that the downhole functionality needs of any given well may change over the life of the well. Specifically, a well may produce fluids at high pressure during the initial life of the well, but the pressure may taper off in the later part. With the initial higher production, the tree needs to be able to handle pressure as high as 15,000 psi. With such a high pressure, there is usually little need to install an ESP or engineer the capability of powering and controlling the ESP through the tubing hanger because the fluid pressure is adequate for fluid production. However, the pressure may taper off to as low as 5,000 psi during the life of the well and may require the use of an ESP. If so, the entire tree and completion may need to be pulled and replaced to add the ESP capability, thus costing the well operator valuable time and money. The initial tree could be designed for ESP functionality, but would result in a higher initial cost of the tree itself. 
    
    
     
       BRIEF DESCRIPTION OF THE DRAWINGS 
       For a more detailed description of the embodiments, reference will now be made to the following accompanying drawings: 
         FIG. 1  is an embodiment of a function spool installed on a well; and 
         FIG. 2  shows example auxiliary port connections that may be used in the function spool. 
     
    
    
     DETAILED DESCRIPTION OF THE EMBODIMENTS 
     In the drawings and description that follows, like parts are marked throughout the specification and drawings with the same reference numerals, respectively. The drawing figures are not necessarily to scale. Certain features of the invention may be shown exaggerated in scale or in somewhat schematic form and some details of conventional elements may not be shown in the interest of clarity and conciseness. The present invention is susceptible to embodiments of different forms. Specific embodiments are described in detail and are shown in the drawings, with the understanding that the present disclosure is to be considered an exemplification of the principles of the invention, and is not intended to limit the invention to that illustrated and described herein. It is to be fully recognized that the different teachings of the embodiments discussed below may be employed separately or in any suitable combination to produce desired results. Any use of any form of the terms “connect,” “engage,” “couple,” “attach,” or any other term describing an interaction between elements is not meant to limit the interaction to direct interaction between the elements and may also include indirect interaction between the elements described. The various characteristics mentioned above, as well as other features and characteristics described in more detail below, will be readily apparent to those skilled in the art upon reading the following detailed description of the embodiments, and by referring to the accompanying drawings. 
       FIG. 1  illustrates an embodiment of a function spool  10  mounted onto a subsea wellhead  12 . Mounted on the function spool  10  opposite the wellhead  12 ,  FIG. 1  also shows a horizontal tree  14 . When the well is drilled and ready for completion, the function spool  10  and the horizontal tree  14  are lowered and installed onto the wellhead  12  using hydraulically operated collet connectors  18 , with seals being formed by appropriate gaskets as shown. Although not shown, appropriate valves for controlling fluid production from the horizontal tree  14  are located in or attached to the horizontal tree  14 . Additionally, any suitable connectors may be used instead of the collet connectors  18 . For example, the function spool  10  and horizontal tree  14  may be attached using a bolted flange. 
     When the well is ready for completion, appropriate plugs are set downhole from the wellhead  12  to maintain fluid pressure. The blowout preventer (BOP) and riser are then removed from the wellhead  12  and the function spool  10  and horizontal tree  14  are installed either in separate sections or both sections at the same time. The BOP and riser are then reattached to the horizontal tree  14  and the plugs removed from the well using an appropriate tool run in through the riser. When installed, the function spool  10  and horizontal tree  14  may then be pressure tested to confirm pressure integrity. 
     A tubing hanger running tool (THRT) is then used to lower a completion, including a tubing hanger  20  and a string of production tubing  22 , through the riser and land the tubing hanger  20  in the horizontal tree  14 . When landed, the THRT actuates a lock ring  21  at the top of the tubing hanger  20  that engages the horizontal tree  14  and locks the tubing hanger  20  in place. It should be noted though that any locking assembly may be used, such as expandable dogs that engage a corresponding profile in the horizontal tree  14 . The production tubing  22  extends below the tubing hanger  20  into the well and the tubing hanger  20  includes an internal bore  24  aligned on one end with the bore of the production tubing  22 . The other end of the internal bore  24  exits the tubing hanger  20  in alignment with a master production port  26  in the horizontal tree  14  for producing well fluids to the surface. Although not shown, the completion includes a rotational alignment means that aligns the tubing hanger  20  with the horizontal tree  14  for aligning the internal bore  24  with the production port  26  as the tubing hanger  20  is lowered into the set position. 
     The completion also includes a function mandrel  30  extending from the production tubing  22  below the tubing hanger  20 . As shown, the function mandrel  30  surrounds the production tubing  22  and is held in place by any suitable connection with the production tubing  22 , such as a threaded connection or welding. Instead of being housed in the tubing hanger  20 , the auxiliary function passages are located in the function mandrel  30  to interact with the function spool  10 . Such auxiliary function passages may be located in any position in the function mandrel  30  and may include passages  32  for electrical, optical, and hydraulic lines that extend downhole alongside the production tubing  22  to control and/or power downhole valves such as a surface-controlled subsurface safety valve (SCSSV), temperature sensors, downhole electric submersible pumps (ESP), downhole processors, and the like, as well as possibly provide for chemical reagent injection. Other types of lines than those listed may also extend downhole from the function mandrel  30 . 
     Corresponding to the functional passages  32  are ports  44  in the function spool  10  that provide access to the function passages  32  from outside the tree for controlling and/or powering the components located downhole. The auxiliary passages  32  typically house connectors that passively wet mate with auxiliary port connectors located in the function spool  10  and may take any suitable form, including vertical or horizontal connectors. The ports  44  in the function spool  10  also include connectors and may also lead to a control unit located subsea or on the surface. Additionally, although the tubing hanger  20  may interact with the horizontal tree  14  to align the radial angle of the tubing hanger  20  and thus the function mandrel  30 , the connection of the function mandrel  30  to the production tubing  22  may be designed to allow a certain amount of function mandrel  30  vertical and rotational movement. The ability of the function mandrel  30  to move allows for a certain amount of tolerance should the connectors not be perfectly aligned when the tubing hanger  20  is in the set position. 
     As an example, the function spool  10  includes an auxiliary passage  32  for housing a hydraulic fluid line  36  that extends downhole to an SCSSV (not shown). The SCSSV controls the flow of fluid through the production tubing  22  from the producing zone. The fluid line  36  extends from the SCSSV and into the function mandrel  30  and routes into a passive coupler  40 . Corresponding with the coupler  40  in the function mandrel  30 , the function spool  10  includes a vertical coupler  42  that can extend from the function spool  10  into alignment with the function mandrel  30  coupler  40  for a vertical stab connection as shown. The stab connection forms a fluid tight connection when the tubing hanger  20  lands in the horizontal tree  14 . From the coupler  42 , a port  44  extends through the function spool  10  and is accessible from outside the function spool  10  by a hydraulic control line  46  that extends to the surface. When connected, the hydraulic control line  46  enables surface control of the SCSSV for well operations. Alternatively, line  36  may be an electrical line for powering a downhole electric submersible pump (ESP) (not shown). 
     Also shown in  FIG. 1  is an example of another auxiliary passage  32  for housing an electrical line  50  for powering an ESP (not shown). The ESP is used to increase the fluid pressure for production fluids through the production tubing  22  from the producing zone. The electrical line  50  extends from the ESP and into the function mandrel  30  and routes into a passive coupler  52 . Corresponding with the function mandrel  30  coupler  52  is a horizontal coupler  54  that can extend from the function spool  10  into engagement with the passive coupler  52  for a horizontal stabbing engagement as shown. The stab connection thus forms a fluid tight connection between the electrical line  50  and an electrical line  56  located in a port  44  that extends through the function spool  10  and is accessible from outside the function spool  10  by an electrical line  60  that extends to the surface. When connected, the electrical line  50  thus enables surface control of the ESP for well operations. Alternatively, line  50  may be a hydraulic line that extends downhole to an SCSSV (not shown). 
     The examples shown are simply two possible types of connections that may be made through auxiliary ports in the function mandrel  30  and accessible from the function spool  10 . It should be appreciated that other types of connections may be made as well and that the connections shown in the examples may be used for different types of communication lines, such as for example, electrical, hydraulic, or optical. Additionally, there may be as many auxiliary ports as a given function mandrel  30  may allow. Because the function mandrel  30  is not being used to support the weight of the production tubing  22 , the function mandrel  30  does not require the robust structural integrity of a support body. 
     With the completion set, the well is ready for production. To create a barrier to fluid from escaping the internal bore  24  through the top of the tubing hanger  20 , plugs  62  are run into the internal bore  24  and set. The BOP and riser may then be removed from the horizontal tree  14  and retrieved. Using the hydraulic control line  36 , hydraulic fluid may be used to open the downhole SCSSV and allow fluid production to flow from the production tubing  22 , and into the production port  26  for flow to the surface or any other desired location. 
     At different times in the life of the well, the well may need additional or different downhole functionalities. For example, as already mentioned, fluid pressure may initially be adequate for fluid production but a downhole ESP may need to be added for production in the future. Additionally, various downhole sensors or processors may need to be added for ongoing production monitoring and management. With the function spool  10  and function mandrel  30 , the horizontal tree  14  and the tubing hanger  20  need be designed for connecting and supporting the production tubing  22 . The various functional connections are no longer made in the tubing hanger  20  but are instead made using passages in the function mandrel  30  and function spool  10 . The well operators may thus change out the function mandrel  30  and function spool  10  on an as needed basis during the life of the well without having to purchase an entirely new horizontal tree  14 , resulting in considerable cost savings. In addition, the horizontal tree  14  and tubing hanger  20  may be made smaller because they no longer need to house the functional connections, resulting in lower costs. Further cost savings result from a smaller horizontal tree  14  and tubing hanger  20  because of the increased mobility in particular of the horizontal tree  14  itself. With a smaller horizontal tree  14  and separate function spool  10 , the horizontal tree  14  and function spool  10  may now be transported and installed on the wellhead  12  separately using lower capacity cranes without requiring as robust equipment as trees that house all of the functional connections. Further cost savings may also be achieved in manufacturing because instead of each horizontal tree  14  being customized for each well, one horizontal tree  14  may be made for a larger number of wells with the function spool  10  and function mandrel  30  may be customized instead. 
     An additional benefit also arises for wells that do not require any downhole functionality to be built into a function spool  10  during the initial production of a well. In those cases, no or minimal functionality may be built into the tubing hanger  20 , such as control for an SCSSV, and the horizontal tree  14  may be installed on the wellhead  12  directly. Later in the life of the well, should additional downhole functionality be needed, the function spool  10  and function mandrel  30  may be added at that time, resulting in cost savings for the well operator from being able to continue using the original horizontal tree  14  and not having to install a full function tree for the initial production. 
     Additional examples of connections through the function mandrel  30  are shown in  FIG. 2  that shows the function mandrel  30  engaging a coupling collar  70  and held in place with a capture ring bolted to the bottom of the function mandrel  30 . Extending into an auxiliary passage  32  is an electrical line  76  for powering and/or communicating with a downhole sensor (not shown), such as a pressure transducer. However, any downhole sensor may be suitable. The electrical line  76  extends from the sensor into the function mandrel  30  and ends with a threaded connector  77  that threads into a connector base  78 . The connector base  78  is held in place by an insulated ring  79  and includes a pin contact  80 . Corresponding with the connector, a power connector penetrator  82  is extendable from the function spool  10  into engagement with the pin contact  80  for a horizontal stabbing engagement as shown. The stab connection forms a fluid tight connection between the electrical line  76  and an electrical line in the port  44  that extends through the function spool  10  and is accessible from outside the function spool  10  by an electrical line that extends to the surface. When connected, the electrical line  76  thus enables power of and/or communication with a downhole electronic device, such as a downhole sensor. 
       FIG. 2  also shows another electrical line  76  for powering and/or communicating with any type of downhole electronic device (not shown), such as a downhole processor. The electrical line  76  extends from the electronic device and into a passage  32  of the function mandrel  30  and ends in a connector base  90 . Extending from the connector base  90  is an electrical contact  92  that extends past a milled portion of the function mandrel  30 . Seals  94  are located in the function mandrel  30  to isolate the milled portion of the function mandrel  30  from fluid pressure in the function spool  10  and flushing ports  96  in the function spool  10  are used to flush the fluid trapped in the milled portion out with appropriate electrical connection fluid. The electrical contact  92  extends into the milled portion and into electrical contact with a contact ring  98  to complete the electrical connection. The contact ring  98  provides a large enough area around the electrical contact  92  that exact placement of the electrical contact  92  with respect to the contact ring  98  is not necessary. Thus, the contact ring  98  does not require exact placement of the function mandrel  30  with respect to the function spool  10 . Although not shown, an electrical line extends from the contact ring  98  in the port  44  that extends through the function spool  10  and is accessible from outside the function spool  10  by an electrical line that extends to the surface. When connected, the electrical line  76  thus enables power of and/or communication with a downhole electronic device, such as a downhole processor. 
     While specific embodiments have been shown and described, modifications can be made by one skilled in the art without departing from the spirit or teaching of this invention. The embodiments as described are exemplary only and are not limiting. Many variations and modifications are possible and are within the scope of the invention. Accordingly, the scope of protection is not limited to the embodiments described, but is only limited by the claims that follow, the scope of which shall include all equivalents of the subject matter of the claims.

Technology Classification (CPC): 4