Title - ASSEMBLY AND COMMUNICATION METHOD WITH A LINE AT THE WELLHEAD

Abstract

An assembly is used for injecting chemicals through a wellhead into a capillary line in a well. A capillary line hanger is installed at the wellhead to support the capillary line. A check valve on the capillary line hanger prevents fluid from flowing back to the wellhead from the supported capillary line. An injection module moves over a gate valve at the wellhead and includes a movable mandrel. Hydraulic pressure applied to a piston chamber in the module extends the mandrel through the open gate valve, allowing a distal end of the mandrel to open the check valve. At this point, the chemical injected into the module can flow through a flow port in the extended mandrel, through the open check valve, and into the supported capillary line in the well.

Description

ASSEMBLY AND COMMUNICATION METHOD WITH A WELLHEAD LINE by Martin Robert Douglas Oliphant, Keith Adams and Robert Andrew Hunt BACKGROUND TO DISCLOSURE

[0001] Sometimes, well operations require running capillary lines downhole from an existing wellhead in a live well. In some situations, a capillary line must be run from the wellhead to the bottom of the well so that chemicals can be injected downhole. In other situations, a hydraulically driven tool must be brought downhole and controlled by a new control line running from the wellhead. For example, an existing safety valve installed downhole may fail because an existing control line to the safety valve has become blocked or damaged. When hydraulic pressure is lost, the existing safety valve closes, and well production is interrupted.Therefore, operators must have and install a surface-controlled underground safety valve and an alternate control line through the wellhead and into the production tubing so that production can be restored.

[0002] These and other situations require operators to extend a capillary line from the wellhead and communicate control fluids, chemicals, or similar substances through the capillary line. Doing this efficiently for a live well can be difficult. To that end, the purpose of this disclosure is to overcome, or at least reduce, the effects of one or more of the problems described above. SUMMARY OF THE DISCLOSURE

[0003] An assembly for communicating a medium through a wellhead to a media line in a well is disclosed herein. The wellhead The 1983390 well assembly has at least one gate valve mounted on the wellhead. The assembly comprises a module, a housing, and a mandrel. The module is configured for installation on the wellhead and is designed to support the media line extending from it. The housing is configured for mounting on the at least one gate valve and has an insertion port for the media. The mandrel is disposed on the housing and has a proximal end and a distal end. The mandrel defines an orifice running from the proximal end to the distal end for the media. The mandrel can move between a retracted and an extended condition. In the retracted condition, the mandrel has its distal end retracted from the at least one gate valve.The mandrel in the extended condition extends through at least one gate valve, has its distal end coupled to the module, and is configured to communicate the media with the media line.

[0004] The module may comprise a hanger configured to support the media line, and the hanger may have an external thread profile configured for installation in the wellhead.

[0005] The module may comprise a valve actuatable at least from a closed condition to an open condition. The valve in the closed condition may be configured to prevent fluid communication through the valve module, while the valve in its open condition may be configured to permit fluid communication through itself. The distal end of the mandrel in the extended condition may be configured to actuate the valve from the closed condition to the open condition.

[0006] The valve may comprise: a seat held in an internal channel of the hanger; a spindle movable in the internal channel, between seating and non-seating conditions relative to the seat; a spindle tip that can be coupled to the distal end of the mandrel; and a component of 1983390 of 24 orientation in the internal channel that orients the spindle towards the seating condition.

[0007] The mandrel may comprise a valve disposed in the bore, the valve being movable between a closed condition and an open condition in response to a differential pressure across it; the valve in the closed condition is configured to prevent communication of fluid through itself; the valve in the open condition is configured to permit communication of fluid through itself.

[0008] The assembly may comprise an orientation element disposed in the housing and which orients the mandrel towards the retraction condition.

[0009] The assembly may comprise a mechanism configured to move the chuck relative to the housing. For example, the mechanism may comprise: a first, movable gear associated with the housing, and a second gear associated with the chuck and coupled to the first gear. In another example, the mechanism may comprise a hydraulic actuator configured to move the chuck by applying hydraulic pressure to a section of the housing.

[0010] The assembly may be operated by hydraulic pressure. The housing may comprise: a first chamber containing the insertion port for the media, and a second chamber containing a hydraulic port for hydraulic pressure. The mandrel may move between the retracted and extended conditions in response to the hydraulic pressure registered in the second chamber.

[0011] The mandrel may comprise a piston section sealed within the housing such that the mandrel can move within the housing in response to hydraulic pressure registered in the housing and applied against the piston section. In this example, the housing may comprise a first annular seal disposed therein that seals an annular space between the housing and the mandrel. The first annular seal may separate the first and second chambers within the housing. The second chamber has a first variable volume defined between the first annular seal and the piston section. In this example, the housing may also 1983390 of 24 comprising a second annular seal disposed in the housing that seals the annular space between the housing and the mandrel. The distal end of the mandrel in both the retracted and extended condition may be disposed beyond the second annular seal.

[0012] In the assembly, the mandrel hole in the extended condition may be configured to communicate: hydraulic lines for the media, from the insertion port to a capillary line supported by the module; an electrical cable for the media, from the insertion port to another electrical cable for the media line supported by the module; or an optical cable for the media, from the insertion port to another optical cable for the media line supported by the module.

[0013] An assembly disclosed herein is operated by hydraulic pressure to inject fluids through a wellhead into a capillary line. The wellhead has at least one gate valve mounted thereon. The assembly comprises a valve module, a housing, and a mandrel.

[0014] The valve module is configured for installation at the wellhead and is configured to support the capillary line extending from there. The valve module is operable from a closed condition to an open condition. In the closed condition, the valve module is configured to prevent fluid communication through it, while in the open condition, it can be configured to allow fluid communication through it.

[0015] The housing is configured for mounting on at least one gate valve. The housing comprises: a first chamber containing an injection port for injecting fluids, and a second chamber containing a hydraulic port for hydraulic pressure. The mandrel is disposed in the housing and defines a bore through itself from a proximal end to a distal end. The proximal end is exposed in the first chamber. The mandrel can move between a retracted condition and an extended condition. 1983390 of 24 extension in response to the hydraulic pressure registered in the second chamber. The mandrel in the retracted condition has the distal end retracted from the gate valve. The distal end of the mandrel in the extended condition extends through at least one gate valve and is configured to actuate the valve module from the closed condition to the open condition.

[0016] A method for communicating media through a wellhead to a communication line in a well is disclosed herein. The wellhead has at least one gate valve mounted thereon. The method comprises: supporting the communication line with a module; installing the communication line and the module through the top of the wellhead; mounting a housing over the at least one gate valve of the wellhead; moving a mandrel disposed in the housing from a retracted condition to an extended condition, with the distal end of the mandrel in the retracted condition retracted from the at least one gate valve; coupling the distal end of the mandrel in the extended condition to the module through the at least one gate valve; and communicating the media from an insertion port in the housing, through an orifice in the mandrel, and into the communication line supported by the module.

[0017] For example, the method may be used to inject fluids through a wellhead into a capillary line in a well. This method may comprise supporting the capillary line with a capillary line hanger; installing the capillary line at the wellhead; mounting a casing over at least one gate valve; moving a mandrel disposed in the casing from a retracted condition to an extended condition, with the distal end of the mandrel in the retracted condition retracted from the at least one gate valve; opening a first valve in the capillary hanger with the distal end of the mandrel in the extended condition through the at least one gate valve into the first valve; and communicating the fluid injection from an injection port 1983390 of 24 in the housing, through a hole in the mandrel and the first valve, and into the capillary line.

[0018] The above summary is not intended to summarize every possible realization or every aspect of the present disclosure. BRIEF DESCRIPTION OF THE DRAWINGS

[0019] Figure 1 illustrates a schematic view of a wellhead supporting capillary lines in a well.

[0020] Figures 2A and 2B illustrate a cross-sectional view of a well connection assembly of this disclosure in an initial operating state.

[0021] Figures 3A and 3B illustrate a cross-sectional view of a well connection assembly of the present disclosure in a later operating state.

[0022] Figure 4 illustrates a detailed cross-sectional view of a spur attached to a capillary line hanger of the well connection assembly.

[0023] Figure 5 illustrates a detailed cross-sectional view of an annular seal of the well connection assembly.

[0024] Figure 6 illustrates a detailed cross-sectional view of a valve for the well connection assembly.

[0025] Figure 7 illustrates the well connection assembly installed in another wellhead implementation.

[0026] Figure 8 illustrates a section of the well connection assembly that has an alternative actuator arrangement.

[0027] Figure 9 illustrates a section of the well connection assembly that has an alternative actuator arrangement.

[0028] Figures 10A and 10B illustrate a cross-sectional view of another well connection assembly of this disclosure in an operational state. 1983390 of 24

[0029] Figures 11A to 11C illustrate schematic views of mandrels from the present disclosure. DETAILED DESCRIPTION OF THE DISCLOSURE

[0030] Figure 1 illustrates a schematic view of a wellhead 10 for a well 12. The wellhead 10 includes a casing head 20 containing a pipe hanger 30 supported thereon. As can be seen, the pipe hanger 30 supports a pipe string 14 in the well 12 and may support some existing capillary lines 18.

[0031] Typically, on the casing head 20, the wellhead 10 has one or more main valves 50, which may be gate valves, to open and close the fluid communication from well 12 to the wellhead 10. On these, the wellhead 10 may have a T-joint (not shown in the figure) with a flow line gate valve (not shown in the figure) and a choke line gate valve (not shown in the figure) connected to the tubing and the other components.

[0032] During operations, a media line for well 12, such as a capillary line, cable, or similar, must be run to the bottom of well 12. For example, an existing capillary line 18 may become clogged, broken, or otherwise rendered inoperable and may require replacement. In this case, the operators will likely need to run a new capillary line 102 into the well. Alternatively, it may be necessary to run a new media line 102 from the surface for a particular purpose, such as connecting to downhole equipment or injecting chemicals. In such circumstances, the operators will need to run the new media line 102 to the bottom of the well, even if the wellhead 10 has already been assembled.

[0033] The present example shows several lines laid to the bottom of the well. These lines can be used for various purposes. Some of the lines 18 may be existing capillary lines laid in well 12. Existing lines 18 would generally be suspended from an existing pipe hanger 30 inside the wellhead 10. For example, one or more lines 1983390 of 24 capillaries 18 can be used as a control line for underground equipment 16 controlled from the surface, such as a hydraulically driven downhole tool, a surface controlled downhole safety valve (SCSSV) or similar, disposed at the bottom of the well 12.

[0034] Some of the media lines 102, 102' may be newly installed media lines, run in well 12, through the existing main valve 50 and other wellhead components 10. If an existing capillary line 18 becomes inoperable, for example, a new media line 102' may need to be run as a hydraulic control line downhole from wellhead 10. In another example, a new media line 102 may be used as an injection line to inject chemicals downhole in well 12. Chemicals are injected from a chemical injection manifold 105 through the capillary line 102 to a chemical injection valve 103 in the well. Chemical injection may be used to reduce corrosion in the well, reduce wax and scale buildup in the well, improve production, and similar purposes.The media lines 18, 102, 102' for wellhead 10 can be used for these and other purposes known in the art.

[0035] Simply running a media line from the top cover of wellhead 10 through the gate valve(s) 50 and other components of wellhead 10 is not appropriate in most cases. To run a media line in the existing wellhead 10, operators would generally need to add a new tubing reel to wellhead 10, modify or replace the lower main gate valve 50 in wellhead 10, perform pipe chipping in wellhead 10, or carry out other retrieval actions that can be cumbersome and complicated. Simply put, disassembling, moving, or replacing parts of the existing wellhead 10 may not be desirable in many instances. 1983390 of 24

[0036] Unlike typical workover actions, a well connection assembly 100 of this disclosure is used instead at wellhead 10. The well connection assembly 100 is installed over wellhead 10 so that the assembly 100 can support a media line 102 or 102' and can enable operators to perform fluid injection, hydraulic fluid communication, make electrical or optical connections, or perform other appropriate operations. The media line 102 or 102' may be a line newly deployed in the well or may already be installed. For example, the well connection assembly 100 can support a capillary line for the media line 102 so that operators can perform chemical injection.In another example, the well connection assembly 100 can support a hydraulic control line for the media line 102' so that hydraulic communication with underground equipment 16 can be performed. In yet another example, the well connection assembly 100 can support an electrical or optical cable for the media line 102' so that hydraulic communication with underground equipment 16 can be performed. The examples that follow will mainly describe an arrangement in which the well connection assembly 100 supports a capillary line for the media line 102 so that operators can perform chemical injection.

[0037] As can be quickly seen in Figure 1, the well connection assembly 100 includes an injection module 104 and a valve module 106. The valve module 106 supports the capillary line 102 and is installed at the wellhead 10 below the gate valves 50. For example, the valve module 106 can be installed on the pipe hanger 30 at the wellhead 10 in an operation similar to that used to install a backpressure valve on a pipe hanger 30. Suitable equipment, such as a service tool, a polished rod, and the like, can be used to install the valve module 106. 1983390 of 24

[0038] As can be seen in Figure 1, wellhead 10 has a lower main gate valve 50 installed in the casing head 20, and the injection module 104 is mounted on the main gate valve 50 at wellhead 10. If an upper main valve (not shown in the figure), a T-joint (not shown in the figure), and the like are present, these components may remain at wellhead 10, and the injection module 104 is mounted on wellhead 10, on the upper cap.

[0039] With assembly 100 installed, an actuating device 107 actuates assembly 100. For example, the actuating device 107 may be a hydraulic (or pneumatic) manifold that supplies hydraulic (or pneumatic) fluids to a hydraulic port 114b on the injection module 104 to actuate assembly 100. While assembly 100 is actuated, an injection manifold 105 injects chemicals, hydraulic fluids, or another type of fluid provided into an injection port 114a of the injection module 104, which may supply them through assembly 100, via gate valve 50, and to the valve module 106 installed on the pipe hanger 30. The valve module 106 may then supply the injected fluid further, via capillary line 102 supported in well 12.

[0040] As can generally be seen, the well connection assembly 100 allows for the execution of a surface-to-downhole fluid connection in well 12 without the need to add a tubing reel to wellhead 10, without the need to convert the main gate valve 50, and without the need to perform other cumbersome or time-consuming operations. At all times, wellhead 10 is protected from surface backpressure from well 12, and the well connection assembly 100 can be deactivated to maintain well integrity.

[0041] Having a general understanding of the well 100 connection assembly, the analysis now moves to Figures 2A and 2B, which illustrate a 1983390 of 24 cross-sectional view of a well connection assembly 100 of the present disclosure, which is hydraulically driven.

[0042] Figure 2A shows most of an injection module 104 from a well connection assembly 100, while Figure 2B shows a remaining section of injection module 104 and a valve module 106 at wellhead 10. As can be seen in Figure 2A, the injection module 104 includes a housing 110 and an internal mandrel 120 that moves within the housing 110.

[0043] As can be seen in Figure 2B, the injection module 104 housing 110 is coupled to the top of the wellhead 10, which may have a number of different components. These components may be present in the wellhead 10 and would depend on the existing implementation. Here, the wellhead 10 includes a casing head 20, a casing hanger 30, a reel adapter 40, and a lower main gate valve 50. Other implementations may have different components for the wellhead 10 than those shown here.

[0044] The casing head 20 has the pipe hanger 30 supported on a settling bell 24 of the wellhead bore 22. The set screws 25 can retain the pipe hanger 30 in place. The pipe hanger 30 can support a string of pipe (not shown in the figure) in the well and can support some capillary control lines 18b.

[0045] Adapter 40 is attached to casing hanger 20 and has an adapter port 42 that communicates with the port in hanger 32. In this example, the chipping modules over conduits 44 are attached to adapter 40 to provide access to the connecting lines 18a that run from adapter 40 to pipe hanger 30. These lines 18a can communicate, via conduits in pipe hanger 30, with the existing control lines 18b supported by pipe hanger 30. Other implementations are possible. 1983390 of 24

[0046] The lower gate valve 50 is coupled to the adapter 40. As usual, the gate valve 50 includes a valve cover actuator 52 that can move a gate 56 within the valve 50 relative to the gate seals 54 to open or close fluid communication through the valve 50. As can be seen in Figure 2B, the lower end of the injection housing 110 of the well connection assembly 100 is coupled over the gate valve 50 in this example.

[0047] Referring back to Figure 2A, the injection housing 110 may include an upper reel 111a that connects to a lower reel 111b, and may include a top cover 113 to close the inside of the housing 110. The modular configuration makes assembly easier, but other configurations can be used for the housing 110.

[0048] The housing 110 includes an injection chamber 112a separated from a hydraulic chamber 112b by an annular seal 124a, which seals against the inner mandrel 120. (Figure 5, discussed below, shows details of the annular seal 124a.) The inner mandrel 120 is movably arranged in the housing 110 against the orientation of a return spring 126 or other orientation element. For example, the spring 126 is a compression spring disposed in the housing 110. An upper end of the spring 126 engages a shoulder of the piston span 125 of the mandrel 120, and a lower end of the spring 126, as shown in Figure 2B, engages a shoulder in the housing 110. Other orientation arrangements may be used.

[0049] As can be seen more clearly in Figure 2A, the mandrel 120 defines a flow orifice 122 through itself from a proximal end to a distal end. In addition, the mandrel 120 includes a first (upper) flow tube section 121a at the proximal end and a second (lower) flow tube section 121b at the opposite distal end. The piston section 125 is disposed between the flow tube sections 121a and has an annular seal 127 that exerts a sliding seal on the housing 110. 1983390 of 24

[0050] The housing 110 includes an injection or insertion port 114a for the insertion or injection of media, chemicals, hydraulic fluids, or the like into the injection chamber 112a. Similarly, the housing 110 includes a hydraulic port 114b for the introduction of hydraulic fluid into the hydraulic chamber 112b. Furthermore, the annular seal 124a keeps the injection fluid in the injection chamber 112a separate from the hydraulic fluid in the hydraulic chamber 112b.

[0051] The hydraulic chamber 112b has a variable volume defined between the annular seal 124a and the piston section 125 with its seals 127. An increase in hydraulic pressure in the hydraulic chamber 112b applies force to the piston section 125 to move the mandrel 120 downward in the housing 110, against the orientation of the spring 126. A reduction in hydraulic pressure in the hydraulic chamber 112b and the return orientation of the spring 126 can move the mandrel 120 upward, in the direction of its retracted position in the housing 110.

[0052] As can be seen in Figure 2B, the distal end of the mandrel 120 includes a spur 130, which may have a check valve 140. As can be seen in Figure 2B, the valve module 106 of the well connection assembly 100 includes a capillary line hanger 150 and a valve 160. The capillary line hanger 150 is installed on a profile 34 of a backpressure valve (BPV) of the pipe hanger 30. For example, an external thread profile 154 on the capillary line hanger 150 can be threaded onto the threaded profile 34 of the BPV of the pipe hanger 30. A sealing ring 155 on the capillary line hanger 150 can exert a seal against the inner bore 32 of the pipe hanger 30.

[0053] The capillary line hanger 150 supports a capillary line 102 by means of a connector 170. The valve 160 is arranged on the capillary line hanger 150 and controls fluid communication with the capillary line 102. In particular, the valve 160 is a non-return valve, a check valve, a vertical spindle valve, or similar device that prevents fluid communication. 1983390 of 24 from the bottom of the well to the wellhead (i.e., preventing backflow pressure from the well) and allowing fluid communication from the wellhead to the bottom of the well (i.e., allowing fluid injection to pass into capillary line 102). (Figures 4 and 6 discussed below show details of capillary line hanger 150 and check valve 160).

[0054] In Figures 2A and 2B, the well connection assembly 100 can be seen in an initial operating state at wellhead 10 prior to injection. Gate valve 50 is closed, and mandrel 120 is retracted to a retracted position in casing 110. In this position, spur 130 at the distal end of mandrel 120 is retracted from gate 56 and seals 54 of gate valve 50, allowing gate valve 50 to operate normally. Conversely, the well connection assembly 100 in Figures 3A and 3B can be seen in a later operating state at wellhead 10 for injection.

[0055] To start injection operations, gate valve 50 is open so that the opening in gate 56 coincides with the gate seals 54, as shown in Figure 3B. Check valve 140 in spur 130 can prevent fluids from entering the orifice 122 of mandrel 120. In addition, check valve 160 in capillary line hanger 150 can prevent fluids from entering above the pipe hanger 30.

[0056] As can be seen in Figures 3A and 3B, hydraulic pressure at hydraulic port 114b pushes the retractable mandrel 120 down into the housing 110, through the open gate valve 50 and into the pipe hanger 30. The spur 130 at the end of the mandrel 120 penetrates the capillary line hanger 150 and opens the check valve 160. The injection fluid (e.g., chemicals, hydraulic fluids, or the like) is pumped into the injection chamber 112a from injection port 114a. The injected fluid can now pass through the mandrel orifice 122 via the open check valve 160 and through the hanger. 1983390 of 24 capillary lines 150 to be transported by means of capillary line 102 further down to the bottom of the well.

[0057] For the injection operation, the mandrel 120 is moved so that its orifice 122 is in fluid communication with the capillary line 102 held at the wellhead 10. In the current examples, hydraulic fluid pushes the mandrel 120 downward to make the connection. Other forms of drive may push the mandrel 120 downward to make the connection. For example, pneumatic drive, as mentioned above, may be used to drive the mandrel 120 to make the connection. In another example, a mechanical drive having a motor, threaded rod, gears, etc., powered by electricity, hydraulic power, pneumatic power, or similar means, may be used to drive the mandrel 120.

[0058] Hydraulic actuation is preferred in most implementations because the well connection assembly 100 can function similarly to a safety valve. If hydraulic pressure is lost (e.g., if the hydraulic manifold fails, if the power supply is interrupted, etc.), the return spring 126 can retract the mandrel 120 in a fail-safe mode to stop injection when the hydraulic pressure drops in the hydraulic chamber 112b. The hydraulic manifold (105) connected to the hydraulic port 114b can be linked to or be part of other systems at the well site, such as a shut-in system, which is used to close the well by closing the gate valve 50.If the shutdown system detects the need to shut down as a result of hydraulic pressure measurements or the like, then the hydraulic manifold (105) can release the hydraulic pressure in chamber 112b so that the manifold 120 retracts by the operation of spring 160, allowing the gate valve 50 to close.

[0059] As can also be seen in Figure 3B, a lower annular seal 124b seals the annular space between the housing 110 and the lower section of the 1983390 of 24 flow tube 121b of the mandrel 120. This seal 124b can prevent well fluids from entering the second variable volume on the other side of the piston section 125, where the spring 126 is located. Well pressure in this volume would prevent the operation of the piston 125. A bleed port 116 can allow evacuation of this volume. Also, if feasible, the port 116 could be used to hydraulically raise the mandrel 120 by injecting hydraulic fluid into the second variable volume between the piston section 125 and the lower annular seal 124b, while simultaneously purging the first variable volume from the hydraulic port 114b.

[0060] Figure 4 illustrates a detailed cross-sectional view of the spur 130 and capillary line hanger 150. The spur 130 can be seen disposed on the distal end of the mandrel 120 and includes a mandrel check valve 140 to control fluid communication with the mandrel orifice 122. The capillary line hanger 150 is installed on the pipe hanger profile 34 and includes a hanger check valve 160. The spur 130 penetrates a receptacle 152a of the capillary line hanger 150, and a distal tip 134 of the spur 130 engages with the check valve 160 of the capillary line hanger 140.The fluid injected from the mandrel orifice 122 can open the mandrel check valve 140, can pass into the spur conduit 132, can pass through the open hanger check valve 160 and can pass into the hanger conduit 152b, so that the injected fluid can enter the capillary line connector 170 (not shown in the figure).

[0061] If the injection pressure at the mandrel port 120 falls below a predetermined value, the mandrel check valve 140 will close, preventing fluid backflow. If the spur 130 is withdrawn from the hanger check valve 140 as a result of a reduction in hydraulic pressure against the mandrel 120, the hanger check valve 140 will close, preventing fluid backflow. 1983390 of 24

[0062] Figure 5 illustrates a detailed cross-sectional view of the annular seal 124a that separates chambers 112a-b from the injection housing 110 and that seals against the outer surface of the mandrel 120. The annular seal 124a may be a threaded gland seal inside the mandrel housing 110, and the annular seal 124a may have internal and external sealing elements for sealingly coupling the housing 110 and the mandrel 120. The internal sealing elements of the annular seal 124a preferably allow sliding sealing with the surface of the mandrel 120, which is movable in the housing 110.

[0063] Figure 6 illustrates a detailed cross-sectional view of the check valve 160 of the capillary line hanger 150. The check valve 160 in this example is a vertical spindle valve, but other valve types may be used. A lower retainer 162b fits into the receptacle 152a of the hanger 150, and an upper retainer 162a is fixed into the receptacle 152a to hold a spindle 164 therein. A spring 166 orients the spindle 164 against a seat 163 in the retainer 162a to interrupt fluid communication from the hanger conduit 152b upward through the check valve 160. When the distal tip 134 of the spur 130 pushes against the spindle 164, it disengages from the seat 163 and exposes the bypass ports 165 in the spindle 164. Fluid can now communicate through the open check valve 160. Although not visible here, the check valve (140) of the spur 130 can be configured in a comparable manner.

[0064] As noted above, the well connection assembly 100 can be used with wellheads of different configurations. Figure 7 illustrates the well connection assembly 100 installed on another wellhead implementation. Here, wellhead 10 is a production tree that includes a production tubing head adapter 40 connected to a production tubing head 20. The lower and upper main valves 50a-b connect over the adapter 40 and a cross with 1983390 of 24 bolts 60 is mounted on top of the upper main gate valve 50b. As is usually the case, a flow line gate valve 62 and a choke line gate valve 64 are connected on opposite sides of the cross with bolts 60, and gate valves 62 and 64 are connected to the other components (e.g., piping, regulators, etc.)

[0065] The main gate valves 50a-b can be opened and closed to control the flow to the well. Gate valves 62 and 64 for the flow line and choke line are used to control the flow line and choke lines (not shown in the figure). The top cover 66 can be removed to provide access to the well for various operations. For example, a capillary line (not shown in the figure) connected to the valve module 106 can be installed through the wellhead 10 using standard procedures, and the valve module 106 can be installed on a pipe hanger 30 on the casing hanger 20. The well connection assembly 100 can then be attached to the top of the crosshead with bolts 60 instead of the top cover 66.

[0066] The wellhead 100 connection assembly can operate as previously described. In the retracted position, the mandrel 120 is retracted from the gate valves 50a-b. In the extended position, the mandrel 120 extends, through the open check valves 50a-b, toward the valve module 106 (with the capillary line hanger 150 and check valve 160) installed on the pipe hanger 30 at the wellhead 10.

[0067] As noted above, the well connection assembly 100 of this disclosure may be hydraulically actuated, but other forms of actuation may drive the mandrel 120 downward to make the connection. For example, a mechanical form of actuation having a motor, threaded rod, gears, etc., could be used to drive the mandrel 120. Figure 8 is an example of such a mechanical arrangement for 1983390 of 24 a drive device 107'. The rest of the components of the injection module 104 can be the same as before.

[0068] The housing 110 includes an opening, box, compartment, etc., for a differential pinion 210 exposed in the lower chamber 112b. The mandrel 120 includes a rack 220 along a portion of its length for meshing with the differential pinion 210. A motor (not shown) for the drive device 107', which may be hydraulic, pneumatic, electric, or the like, can rotate the differential pinion 210 to lower the mandrel 120 to its extended condition for fluid connection. The motor for the drive device 107' can reverse the rotation to raise the mandrel 120 to its retracted condition, or a torsion spring (not shown) in the differential pinion 210 can reverse the rotation of the differential pinion 210 upon release of the motor or a clutch device. Appropriate sealing is applied so that the housing 110 seals the differential pinion 210 and the rack 220.For example, a rotary seal 212 can be supplied for the differential pinion 210, and a gland seal 124b can be used between the housing 100 and the mandrel 120 to seal the rack 220.

[0069] Figure 9 is an example of another mechanical arrangement for a drive device 107' in the form of a worm gear elevator. The housing 110 includes an opening, box, compartment, etc., for a worm gear 230 meshed with a worm gear 240 exposed in the lower chamber 112b. The mandrel 120 includes a worm gear 250 along a portion of its length to mesh with a threaded internal of the worm gear 240. A motor (not shown in the figure) for drive device 107', which may be hydraulic, pneumatic, electric, or the like, can rotate the worm gear 230, which rotates the worm gear 240, to bring the mandrel 120 to its extended condition to perform the fluid connection. The motor for the drive device 107' can reverse the rotation to raise the chuck 120 to its retracted condition, or A torsion spring (not shown) in the worm gear 230 can reverse the rotation of the worm gear 240 upon release from the motor or a clutch device. Suitable sealing is provided so that the housing 10 seals the worm gear 230 and the worm gear 250. For example, a rotary seal 212 may be supplied for the worm gear 230, and a gland seal 124b may be used between the housing 100 and the mandrel 120 to seal the worm gear 230.

[0070] As will be seen, the necessary bearings, shafts, sleeves and other devices do not appear in Figures 8 and 9. These and other forms of mechanical configurations may be used.

[0071] As noted above, the well connection assembly 100 can be used to communicate hydraulic fluids and chemicals through the wellhead 10, but other forms of media can be communicated by means of the well connection assembly 100 through the wellhead 10. For example, physical connections for electrical and optical communications can also be achieved by means of the disclosed assembly 100.

[0072] Figures 10A and 10B show an example of the wellhead connection assembly 100 that provides a connection for electrical and optical communications according to this disclosure. Assembly 100 includes components similar to those in other embodiments discussed above, and therefore the same reference numbers are used for similar components. As can be seen here, the housing 110 mounted on the wellhead 10 includes an insertion port for the media, specifically an insertion assembly 200 for inserting a capillary line, an electrical cable, an optical fiber cable, or another type of media line into the housing 110. The insertion assembly 200 may include a junction box, cable glands, hangers, couplings, and other components used in the art. The media lines 202 / 204 may include a cable used for an implemented electric submersible pump (ESP) system.In another example, media lines 202 / 204 can be used to have fiber optic lines. 1983390 of 24 to the bottom of the well to a reservoir monitoring system with fiber optics through the production tubing or similar.

[0073] In a simple arrangement, a media line 202 can be inserted through the insertion assembly 200 and run through the mandrel 120 inserted into the pipe hanger 130. If a backpressure valve (not shown in the figure) is present in the pipe hanger 30, the media line 202 can pass through the valve and open it. From there, the media line 202 can be run further down the well from the wellhead 10. If the mandrel 120 were retracted, however, the media line 202 would still pass through the gate valve 50. The media line 202 would need to be broken or retrieved for the gate valve 50 to close.

[0074] In another arrangement, a media line 202 can be inserted through the insertion assembly 200 to make a connection with another media line 204 held on a hanger 151 at the wellhead 10. A coupling 210, for example, at the end of the media line 202, can make a connection with another coupling 212 for the media line 204 held on the hanger 151. The coupling 210 can be held on the distal end or spur of the mandrel 120, so that the connection can be made while the mandrel 120 is moved and inserted into the hanger 151.

[0075] The mandrel 120 can be driven as before, so that the distal end is inserted into the hanger 151, as shown in Figure 10B. This insertion can open a one-way valve (not shown in the figure), such as a hinge valve or other type of valve, in the hanger 151 if present. The media line 202 of the well connection assembly 100 can, in this way, be connected to the media line 204 in the well through the connection of couplings 210, 212.

[0076] If mandrel 120 were removed from this arrangement, the media line 202 that passes through the trim box 200 could be disconnected from the 1983390 of 24 hanger 151 on couplings 210, 212, and could go up through gate valve 50 with mandrel retraction 120.

[0077] Figures 11A to 11C illustrate schematic views of mandrels 120 of this disclosure. As can be seen in Figure 11A, and consistent with previous arrangements, the mandrel 120 can be a unitary component having an upper section of flow tube 121b, a piston section 125, and a lower section of flow tube 121a. As can be seen in Figure 11B, the mandrel 120 can be formed from two or more components, facilitating assembly. For example, here, the upper section of flow tube 121b and the piston section 125 can form a unitary component with the lower section of flow tube 121a connected (e.g., threaded). An opposite arrangement can be used, or the three components 121a and 125 can be separate elements.

[0078] Finally, as can be seen in Figure 11A, the above arrangements for mandrel 120 require the housing of the assembly to extend a given height h so that the upper section of the flow tube 121b can maintain a ground seal with the upper seal 124a as the mandrel 120 descends. The required height H can be reduced by using a telescoping arrangement for the mandrel 120.

[0079] For example, Figure 11C illustrates a schematic view of a telescoping mandrel 120 of this disclosure, wherein the mandrel 120 is comprised of two or more telescoping components. Here, the lower tube section 121b' and the piston section 125 may be a single component, while the upper tube section 121a' is a telescoping component disposed within the lower tube section 121b'. The telescoping components use appropriate seals and stops (not shown in the figure). An edge of the upper tube section 121a' may be in contact with a shoulder 115 or similar feature of the assembly housing. Downward movement by hydraulic pressure against the piston section 125 may move the lower tube section 121b' downward, along the entire length of the upper tube section 121a', against the orientation of the 1983390 of 24 spring 126. The upper seal 124a maintains a seal with the upper section of tube 121a'; the lower seal 124b maintains a seal with the lower section of tube 121b', and an intermediate seal 124c provides a seal between the tube sections 121a' and 121b'. This movement of the telescoping sections 121a' and 121b' may reduce the height required for the housing of the assembly, but the arrangement would increase the number of possible leak paths that would need to be properly sealed.

[0080] The foregoing description of preferred embodiments and other embodiments is not intended to limit or restrict the scope or applicability of the inventive concepts conceived by the Applicants. It shall be appreciated, with the benefit of this disclosure, that the features described above in accordance with any embodiment or aspect of the disclosed object may be used, either alone or in combination with any other described feature, in any other embodiment or aspect of the disclosed object.

[0081] In exchange for the disclosure of the inventive concepts set forth herein, the Applicants desire all patent rights permitted by the appended claims. Therefore, the appended claims are intended to include all modifications and alterations to the full extent of those within the scope of the following claims or their equivalents. 1983390 of 24 CLARKE MODET & CO. (ARGENTINA) SA - 30540437455 Digitally signed by PORTALTRAMITES - INPI Date: 2022.09.29 09:58:46 -03:00 Reason: Digitally Signed by the INPI Location: Buenos Aires, Argentina 1983390

Claims

1. An assembly (100) for communicating a medium through a wellhead (10) to a medium line (102, 204) in a well, the wellhead (10) having at least one gate valve (50) mounted on a wellhead (10), the assembly (100), characterized in that it comprises: a module (106) configured for installation on the wellhead (10) and configured to support the medium line (102, 204) extending therefrom; a housing (110) configured for mounting on the at least one gate valve (50) and having an insertion port (114a, 200) for inserting the medium into the housing (110);and a mandrel (120) disposed in the housing (110), having a proximal end (121a) and a distal end (121b, 130), wherein the mandrel (120) defines an orifice (122) through itself from the proximal end (121a) to the distal end (121b, 130) for communicating the means through the mandrel (120), the mandrel (120) being movable between a retracted condition and an extended condition, the mandrel (120) in the retracted condition having the distal end (121b, 130) retracted from the at least one gate valve (50), the mandrel (120) in the extended condition extends through the at least one gate valve (50), with the distal end (121b, 130) coupled to the module (106) and configured to communicate the means with the means line (102, 204). Fourteen claims follow;