|Publication number||US3454084 A|
|Publication date||Jul 8, 1969|
|Filing date||Oct 10, 1967|
|Priority date||Oct 10, 1967|
|Publication number||US 3454084 A, US 3454084A, US-A-3454084, US3454084 A, US3454084A|
|Inventors||Sizer Phillip S|
|Original Assignee||Otis Eng Corp|
|Export Citation||BiBTeX, EndNote, RefMan|
|Patent Citations (6), Referenced by (19), Classifications (16)|
|External Links: USPTO, USPTO Assignment, Espacenet|
1 8, 1969 P. s. SIZER WELL HEAD CLOSURE ASSEMBLY Sheet Filed Oct. 10, 1967 R m m w 6 N w R m g WI O" .l a g N S W 0 F 0 l A 0 a S 5 5 l D. Pl :1 y Y B n a J v 0 c 5 5 75 3 6 7 W 5 V a a ww F ooo 1 1 v 1 6 Wur w a 7 W C 2 m 5 "a 4 mm 5 H p y 3, 1.969v P. s. SIZER I WELL HEAD CLOSURE ASSEMBLY Filed Oct. 10, 1967 INVENTOR II-u M Phillip s Sizer BY B WW July 8, 1969 P. s. SIZER 3,454,084
WELL HEAD CLOSURE ASSEMBLY Filed Oct. 10, 1967 Sheet 3 of 4 -l l ?l Ill! F Z 233 p W227 2 9 A w f a 2I9\" 56 226 23 F2 '2 30 f Fl w "#k -3o4 a 299 l 305 if X a 220 i /7 225 Q I TA 20 E INVENTOR 22/ Phillip S. Sizer 34 p gyfllw ay'm July 8,1969 v P. SSIZER 3,454,084
WELL HEAD CLOSURE ASSEMBLY Filed Oct. 10, 1967 Sheet 4 of 4 INVENTOR Phillip s. Sizer 1 MW BYWWXM'M Fig.4
United States Patent 3,454,084 WELL HEAD CLOSURE ASSEMBLY Phillip S. Sizer, Dallas, Tex., assignor to Otis Engineering Corporation, Dallas, Tex., a corporation of Delaware Filed Oct. 10, 1967, Ser. No. 674,285 Int. Cl. E21b 33/035, 43/01; E21c 19/00 US. Cl. 166.6 Claims ABSTRACT OF THE DISCLOSURE A well head closure assembly for remote or under water wells arranged to provide vertical access into the tubing strings in the well and having lateral flow wings through which fluids may flow from the well or be pumped into the well to install, remove or actuate various well tools in the well and to carry out various service operations on the well; and flow controlling valve means disposed in the well head closure assembly having passages directing flow of fluids into and out of the tubing string and lateral flow passages of the well head closure assembly and operable under remote control to close off all flow through the conductor. One form of the closure assembly carries the lateral flow wings, and in another form a removable sleeve is inserted in a well head having the lateral flow wings thereon, and oriented into position to communicate the tubing strings with the lateral flow wlngs.
This invention relates to well tools, and more particularly to well head equipment especially adapted for use at remote or underwater locations.
An important object of the invention is to provide a well head closure apparatus lowerable into and seatable in a well head at the bottom of a body of water for supporting a plurality of strings of flow conductor pipe or tubing in the well, and having means providing lateral flow passageways communicating with lateral flow lines connected with the well head.
A further object of the invention is to provide a well head apparatus of the character described wherein the support means provides for direct vertical access into the well casing and tubing through the well head, and may be used to support the tubing flow strings in the well casing in flow communication with the lateral flow lines of the well.
Still another object of the invention is to provide in a well head apparatus of the character described a closure apparatus for closing the well vertically at the upper end, and which is removable from the well to permit re-entry thereinto in order to service or perform other operations on the well.
A particular object of the invention is to provide in tus includes a closure head having flow control valvesv removably disposed therein and removable vertically therefrom through suitable apparatus attached to the well head; said well head apparatus having orienting means for aligning the lateral flow passageways from the cflow conduits of the well to the lateral flow lines of the well in predetermined manner, to permit removal and reinstallation of the well tubing strings, if desired, without disturbing the lateral flow lines.
3,454,084 Patented July 8, 1969 Still another object of the invention is to provide a well head apparatus of the character described which has means controlled from a remote position to anchor the same in place and to release the same from anchored position when desired.
A further particular object of the invention is to provide, in a well head closure apparatus of the character set forth, flow control apparatus removable vertically from the closure apparatus and provided with flow passages communicating with the lateral flow wings of the closure apparatus or well head, said flow control apparatus having means for remote control of the actuation thereof. Another object is to provide in such a flow control apparatus and well head closure assembly, means for orienting the 'well head closure assembly of the character described and having means for installing, locating, locking and removing the same in the vertical passage of said well head closure apparatus, and means for equalizing pressures across the device to permit removal thereof through the vertical passage.
Another object of the invention is to provide, in a well head closure assembly of the character described, means protecting the vertical passageways of the well head closure member and the flow control devices located therein against deterioration by entry of fluid, mud, or other foreign matter.
A further object of the invention is to provide a well head apparatus of the character described, which provides for removably supporting the tubing strings in the well head in sealing engagement therewith, and wherein means is provided for retaining the upper ends of the tubing strings in place of the tubing string in the well heads, one of which means may be the closure apparatus or flow controlling valves removably installed in the vertical passages of the well head apparatus.
Additional objects and advantages of the invention will be readily apparent from the reading of the following description of a device constructed in accordance with the invention, and reference to the accompanying drawings thereof, wherein:
FIGURE 1 is a view, partly in elevation and partly in section, showing a schematic well installation having a plurality of flow conductors disposed in the well supported from a permanent well head structure at the bottom of the body of water, and showing the removable well head apparatus and flow control devices of the invention assembled therewith;
FIGURE 2 is an enlarged view, partly in elevation and partly in section, taken on the line 22 of FIGURE 5, of the upper portion of the well of FIGURE 1, showing the well head apparatus of the invention having a flow control device disposed therein;
FIGURE 2A is an enlarged view of the latching mechanism for holding the well head apparatus connected to the permanent well head structure;
FIGURE 2B is an enlarged fragmentary sectional view showing a modified form of tubing support in the well head apparatus;
FIGURE 3 is an enlarged view, partly in elevation and partly in section, taken on the line 3-3 of FIGURE 6, showing a modified form of the well head apparatus for use with more than two flow conductors, and showing a removable sleeve for supporting the tubing strings engaged within a permanently installed lateral flow wing head forming a part of the permanent well head structure;
FIGURE 3A is an enlarged view, partly in elevation and partly in section, showing a modified form of support for the tubing strings for use in the removable sleeve of the well head apparatus of FIGURE 3;
FIGURE 4 is a view, similar to FIGURE 3, showing means for connecting a vertical conductor to the well head for raising and lowering the same or for lowering well tools into and out of the bores of the apparatus of FIGURE 3;
FIGURE 5 is a top plan view, with portions broken away, showing the single lateral flow wing of FIGURE 2 in which two tubing strings are supported in the well; and,
FIGURE 6 is a top plan view, partly in section, showing the well head apparatus of FIGURE 3, having two lateral flow wings providing communication with four tubing strings disposed in the well bore.
In the drawings, FIGURE 1, a typical well head installation is illustrated schematically, in which a surface casing 10 having a well casing head 11 at its upper end sup ports by means of a sleeve 12, a surface string of casing 13 having at its upper end an outer casing hanger 14 provided with locking recesses or grooves 15 and a sealing surface 16 therein (FIGURE 2) for supporting the usual production strings of casing 17 and 18. While only a single production string of casing 13 is shown schematically in FIGURE 1, it is obvious that more than one string may be supported in the head 14, as shown in FIGURE 2, if desired.
The casing string 17 is suspended from a casing hanger 19, and the production casing string 18 is suspended from a casing hanger 20, as shown in FIGURE 2. The casing hanger 19 is locked in place in the outer hanger 14 by locking means 21 engaged in the lower recess 15 in the outer hanger, while the inner production casing string 18 carried by the hanger is locked in the outer hanger by locking means 22 engaged in the upper recess 15 in said outer casing hanger. The structure just described comprises a common type of well head installation.
The bore of the casing hanger 14, above the upper production string hanger 20, is provided with an internal annular locking recess 25 and a sealing surface 26. One form of the well head closure apparatus H of the invention is telescoped into the upper end of the bore of the casing hanger 14 and locked in place therein by locking dogs 27 which are engaged in the locking recess 25 in the bore of the hanger. The lower end of the closure apparatus H is beveled and seats on the upper end of the inner production casing hanger 20.
The closure apparatus H includes a body member 30 which is provided with a pair of laterally spaced parallel longitudinal flow conduits or passages 31 and 32 which extend throughout the length of the closure member and are provided at their lower ends with threads (FIGURE 2A) for receiving the threaded upper ends of tubing strings 33 and 34, respectively, whereby the tubing strings are suspended from the well head closure apparatus.
Suitable landing nipples 35 for well tools are disposed in each of the tubing strings below the well head closure body member, and other flow control devices, such as laterally opening slidable sleeve valve assemblies 36, may be disposed in each of the flow strings to establish circulation between the casing annulus and the bore of the particular tubing string in which each of them is mounted. At the lower end of the string 33 is mounted a landing nipple 37 in which a flow control device 38 is disposed. A cross-over coupling member or packer 39 connects the lower ends of the tubing strings 33 and 34 and is provided with a lateral port 40 to effect flow communication between the two tubing strings at that point. Suitable packing or sealing means 41 is disposed on the exterior of the cross-over packer 39 for sealing with the casing at that point.
Below the packer or cross-over member 39, the tubing strings are each provided with a landing nipple 42 in which suitable valves for controlling fiow through the tubing strings may be installed. A valve 43, which may be a back flow check valve, is shown disposed in the landing nipple 42 connected to the tubing string 34. Perforated nipples 44 are provided below the landing nipples 42 at the lower end of each of the tubing strings for communicating with the producing formation through perforations 45 at the lower end of the production casing string.
The exterior of the casing head 11 is provided with an external annular flange connecting means 11a by means of which the usual blow-out preventers (not shown) and other well control apparatus may be connected to the upper end of the casing head to permit landing the several strings of casing in the well bore, and to permit lowering the well head closure apparatus H into place.
The present invention is concerned with the well head closure assembly H for closing the top of the well, sup porting the tubing string therein, and providing for control of flow of fluids from the tubing strings to lateral flow lines connected with such well head closure assembly. The well head closure body member 30 has lateral flow lines or conduits 51 and 52 provided therein communicating with the vertical passages 31 and 32, respectively, of the body member and with the bore of the tubing strings therebelow. The vertical passages 31 and 32 of the closure member provide for vertical entry and removal of the flow control devices or valves 55 and 56, and for permitting other well apparatus to be inserted into and removed from the tubing strings 33 and 34 in the well, and to provide access to the well bore therebelow when desired. The lateral flow wing 50 of the well head closure assembly is formed with the two arcuate flow passages 51 and 52 which communicate with the vertical passages 31 and 32, respectively. The flow wing and the flow passages therein are connected by means of a coupling C with the lateral flow lines F1 and F2 from the well head to a remote point or to a platform or other support means above the surface of the body of water in which the well is located. The arcuate passages connected to the flow lines F1 and F2 provide for circulation of fluid from the flow line F1 through the passage 51 of the body into the vertical passage 31 and thence into the tubing string 33 therebelow, from whence it may cross through the passage 40 in the cross-over device 39 into the tubing string 34, and then flow back out of the well through the tubing string 34, through the lateral flow passage 52, and thence to the flow line F2, or vice versa. It will therefore be apparent that various well apparatus may be circulated into and out of the tubing strings by fluid pump-down operation in the manner set forth in the patent to Schramm et 21., 3,040,808, issued June 26, 1962. The reverse flow of fluids may be accomplished, if desired. The sliding valves 36 may be actuated by the pump-down equipment, or various types of flow controls, such as the devices 38 and 43, may be circulated into and out of the well by such pump-down equipment.
The body member 30 of the well head closure assembly is provided at its lower end with a plurality of lateral apertures 60, in each of which one of the locking dogs or lugs 27 is disposed for lateral expansion and contraction. An annular expander member 61 is slidable in an annular recess formed in the body and is beveled at its lower end and adapted to engage between the lugs 27 and the body to hold the lugs in the expanded position as shown in FIGURE 2A. The expander member is biased downwardly toward the locking position, shown in FIGURE 2A, by a spring 62 disposed between the enlarged upper piston head 63 of the expander member and the shoulder 64 formed at the upper end of the enlarged annular pressure recess or cylinder 65 provided in the body member for receiving the enlarged piston head of the expander member.
For moving the expander member 61 upwardly from looking engagement with the dogs 27, fluid pressure from a remote point, such as at the surface of the ground or work platform, is introduced through a fluid pressure conduit line or passage 66 formed in the lateral flow wing 50 and communicating at its lower end with the lower portion of the annular cylinder 65 below the piston head 63 of the expander member. The fluid pressure is confined between a lower O-ring 67 and an upper O-ring 67' disposed in suitable annular recesses in the outer wall of the cylinder and engaging the outer periphery of the cylinder head and of the reduced lower portion of the expander member. The fluid pressure thus acts against the under side of the piston head to move the piston head and the expander member 61 upwardly against the force of the spring 62 to withdraw the lower portion of the expander member from engagement with the dogs'to permit the dogs to move inwardly to retracted position. A vent line 68 is formed in the flow wing and the body 30 of the head closure communicating at its lower end with the upper portion of the cylinder 65 and also leading through the flow wing 50 to a remote point at the well surface, whereby, if desired, fluid pressure may be introduced into the upper portion of the cylinder to act on the piston. In such event a seal (not shown) would be disposed in the inner wall of the cylinder opposite the upper seal 68. Also, the conduit 68 provides for venting fluid pressure in the upper portion of the cylinder as the piston head and plunger are moved upward therein to permit the same to be moved without resistance of pressure applied thereagainst.
The operating fluid pressure lines 66 and 68 communicate with similar lines or conduits formed in the flow lines F1 or F2, or with small separate conduits or lines connected at their ends to the coupling member C and communicating with the conduits 66 and 68.
When the closure head assembly H is disposed in the upper end of the casing hanger 14, it will be seen that the tubing strings 33 and 34 are supported thereby within the production casing 18 in the usual manner.
Each of the flow control valves 55 and 56 disposed in the passages 31 and 32 in the control head assembly includes an upper locking assembly 70 having a laterally expansible dog 71 disposed in a cage 72 and adapted to be expanded by an expander member 73 movably downwardly by a connector head 74 formed at the upper end of the expander sleeve, so that the expander member is movable between the dogs and outer surface of the upper end of the mandrel. Such a locking device is illustrated in the patent to Tamplen, No. 3,208,531, issued Sept. 28, 1965. The mandrel 75 of the flow control device is provided with an axial blind bore 76 which extends downwardly to a point below the locking assembly and has a sliding sleeve valve 77 disposed therein for closing lateral ports 78 and 79 communicating with the bore. The port 78 communicates with the exterior of the mandrel while the port 79 communicates at its opposite end with an elongate arcuate fiow passage 81 which extends upwardly from the longitudinal bore 84 in a diverter head section 80 at the upper end of a valve assembly 85 connected to the lower end of the mandrel. The passageway 81 is arcuate and communicates at its upper end with the lateral arcuate flow pressure 52 in the flow wing 50. The valve assembly 55 is substantially identical in construction to the valve assembly 56 just described and closes the upper portion of the bore 31 of the head. The lateral flow passage 81a in the diverter head 80a of the valve 85a communicates with the passage 51 of the flow wing 50 to divert the fluid string 33 to the flow passage 51. The valve assembly 85 in the flow control device 56 is shown to be a ball type valve which is normally held in the open position by fluid pressure acting downwardly on a piston 89 in the valve to cause the valve operator mechanism to move the valve to the closed position. A valve of the type just mentioned is illustrated and de- 6 scribed in the co-pending application of William W. Dollison, Ser. No. 510,189, filed Nov. 29, 1965.
For orienting the mandrel of the flow control device to position the arcuate flow diverter passage 81 in alignment with the lateral passage 52 and the flow wing 50, an arcuate camming surface 91 is formed on the lower portion of the mandrel and is adapted to engage a guide lug 92 disposed in the lower portion of the bore 32 of the closure head and engaging the camming surface to turn the flow control valve about its longitudinal axis to correctly orient the diverter passage 81 with respect to the flow passage 52. An O-ring 95 is disposed on the mandrel above the upper end of the diverter passage 81 and engages the wall of the bore 32 to seal off above the lateral flow passage and the open end of the diverter passage, while a similar O-ring 96 is disposed in a recess on the exterior of the flow control device mandrel below the lateral outlet of the diverter passage 81 and seals between the bore wall of the passage or bore 32 and the mandrel below the lateral outlet 81 and the inlet to the lateral passage 52. Thus, fluid pressure is directed from the passage of the valve assembly 85 into the lateral flow passage 52 in the flow wing and thence to the flow line F2.
A lower seal member 97 is disposed in an annular groove formed on the exterior of the mandrel of the valve assembly spaced below the ring 96 and provides for introduction of operating control fluid from a flow control fluid line 99, which is formed in the well head body and communicates at its lower end with the bore of the passage 32 between the seal rings 96 and 97 whereby operating fluid may be directed into the valve assembly to move the valve assembly to open position. The flow line 99 extends along the lateral flow wing to the coupling C and may also be formed in the lateral flow wing F2 or the flow line F1, or may be a separate line connected to the coupling C and extending to the surface or other remote point for operation of the device.
The sleeve valve 78 has seal members at its upper and lower ends engaging the wall of the bore 76 on opposite sides of the lateral ports 78 and 79 to close off entry of fluid through those ports into the open axial bore 76 at the upper end of the mandrel. When the valve 78 is in the position shown in FIGURE 2, obviously flow cannot take place through the lateral ports and all flow is directed from the tubing string 34 through the bore '84 of the valve assembly 85 and thence through the diverter passage 81 into the lateral flow passage 52 in the flow wing 50, and thence to the flow line F2. Similarly, the valve 55 in vertical bore or passage 31 directs flow from the tubing string 33 through a diverter passage 81a into the lateral flow passage 51 and the flow line F2 connected therewith by the coupling C.
The valve assembly and its locking mandrel with its diverter passage formed therein may be run into the well by'wire line or flexible line lowering tools (not shown), in the same manner as the well tools illustrated in the patent to Tamplen, mentioned hereinabove. The orientingf cam surface 91 engaging the orienting lug 92 will correctly dispose the upper end of the arcuate diverter passage 81 in alignment with the arcuate flow passage 52 and the lateral flow wing passage 51. Thus, it will be seen that the well flow is directed from the tubing strings to the lateral flow lines F1 and F2 by means of the diverter heads and 80a having the diverter passages 81 and 81a formed therein, while flow upwardly out of the bores 31 and 32 of the closure head assembly is prevented by the sleeve valve closing the upper passage or bore 76 of each of the mandrels.
Should it ever become necessary to equalize pressures on opposite sides of the ball valve assembly 85, the sleeve valve 77 is moved downwardly by a suitable prong or other tool engaging the upper end thereof and driving the same downwardly below the lateral flow ports 78 and 79. When this occurs, fluid pressure may be introduced from a conduit connected with the flow passage 32 into the arcuate diverter passage 81, or pressure in such passage may be relieved or equalized across the entire assembly to permit removal of the locking device and the valve assembly with the diverter head section upwardly out of the bore in the well head closure assembly.
A suitable lubricator (not shown) may be threaded into the screw threads 31a and 32a at the upper ends of the passages in the closure head, and access provided in the usual or customary manner to the bore of the tubing through such conduits or lubricators.
Also, if desired, a lubricator or running and pulling tool R such as shown in FIGURE 4 may be connected to the upper end of the well head assembly H to provide direct access into the separate bores through a common vertical passage. Such a lubricator device is illustrated in the patent to Raulins, No. 3,103,591, issued Sept. 3, 1963, and includes a body 110 having a sleeve 111 slidable on its exterior and actuated by hydraulic fluid directed into the bore of the sleeve 111 through operating fluid lines 112 and 113. Operating fluid pressure directed into the bore of the sleeve 111 through the line 112 moves the sleeve downwardly to the position shown in FIGURE 4, while pressure introduced through the operating fluid line 113 directs fluid into the bore of the sleeve above the flange 114 on the body 110 and moves the sleeve upwardly to withdraw the locking member 115 at the lower end of the sleeve from locking and holding engagement with the locking dogs or ring sections 116 carried in the apertures in the lower portion of the body 110 and engaging in the annular locking recess 120 at the upper end of the well closure head assembly below the locking flange 119 formed thereon. The tubing 121 connected with the upper end of the body 120 is open to provide access into both passages 31 and 32 in the closure head assembly, while a seal sleeve 122 carried in the bore of the body 110 has packing means 123 on its exterior engaging in the upper enlarged bore of the closure head assembly. While the closure head assembly shown in FIG- URE 4 differs somewhat from that of FIGURE 3, the latching coupling member could be connected to the head assembly of FIGURE 2 in the same manner, and seal 123a provided in the bore of the body 110 seals against the exterior of the head assembly.
Normally, the bore of the passages 31 and 32 above the flow control devices 55 and 56 are filled with grease or other corrosion inhibiting materials, and a closure cap 130 is telescoped over the upper end of the head assembly, and has detent fingers 131 disposed in its interior and engaging in the recess 120 below the shoulder 119 on the exterior of the upper portion of the closure head. The closure cap is also similar to the closure cap shown in the patent to Raulins No. 3,102,591, and carries a seal 132 in its lower portion engaging the lower portion of the exterior of the upper projecting neck 133 of the head assembly to seal therebetween to prevent entry of fluid such as sea water and the like into the passages 31 and 32.
It is also believed readily apparent that a connector or lubricator such as is shown in FIGURE 8 of the patent to Raulins may be connected to the upper end of the closure head assembly, if desired, to provide for oriented access into a selected one of the passages 31 and 32 in the closure head assembly. In such event, a suitable orienting device such as is shown in the Raulins patent would be provided on the upper end of the projecting neck of the closure assembly.
From the foregoing, it will be seen that a closure head assembly H has been illustrated and described which is lowerable into a Well casing to support the tubing strings or flow conductors in said casing and provided with a lateral flow wing having lateral flow passages formed therein communicating with the tubing strings or flow conductors in the well for directing fluids from the well through the tubing strings and the lateral flow wing to the flow lines leading to the surface or other remote point.
It will readily be seen that the valve assemblies 55 and 56 serve as flow control valves and may be readily removed from the vertical bores in the well head closure member after suitable lubricators have been connected to the upper end of the well head whereby the valve assemblies may be lifted from the well head and access provided through the well head to the tubing strings to perform various operations therein.
It will also be seen that the valve assemblies are provided with lateral flow diverting passages which are removable therewith and which are oriented into correct alignment with the lateral flow passages in the well closure head by orienting means in the vertical passages of the well head and on the flow control devices.
It will also be seen that the valves are openable and closeable by fluid pressure from a remote point to control flow from the well through the lateral flow wings, if desired. The valves thus would function in the same manner as the usual flow control valve or Christmas tree valves of the usual well installation at the well head.
It is believed readily apparent that, as shown in FIG- URE 2B, the tubing strings 33 and 34 may be removably supported in the lower end of the bore of the well head closure assembly H, whereby the tubing strings may likewise be removed from within the well bore through the well closure head, if desired. The lower portion of each of the vertical or longitudinal bores 31 and 32 of the well head are reduced at their lower portion to provide a beveled stop shoulder and seal surface 141 in the lower portion of the bores 31 and 32. While only the bore 31 is shown in FIGURE 2B, it is obvious that the identical structure may be provided in the bore 32. A hanger or head member 142 having an enlarged upper portion or head 143 provided with an O-ring or other suitable seal member 144 in an annular groove in its exterior has a downwardly facing beveled shoulder 145 formed thereon which is adapted to engage the upperly facing shoulder 140 in the lower portion of the bore 31 of the closure head. A tubing string is threaded into the coupling portion 146 at the lower end of the support head or hanger member, and when the hanger is landed in the closure head bore, as shown in FIGURE 2B, the lower end of the valve assembly 55 is adapted to engage the upper end 148 of the hanger 142 to prevent upward movement thereof. The seal ring 144 prevents fluid flow between the air and the bore of the head in the usual manner. With the structure just described, it is apparent that the valve assembly 55 may be removed from the bore 31 in the manner already described, and a string of tubing or other suitable lifting means having screw threads on its lower end lowered into the bore 31 of the closure head and engaged in the upper threads 147 in the bore of the hanger whereupon the hanger and the tubing string supported thereby may be lifted from the well through the bore 31 of the closure head assembly. The diameter of the coupling portion 146 of the hanger is equal or slightly greater than the external diameter of the couplings joining the several sections of the tubing therebelow so the tubing string will readily pass through the opening below the shoulder 145 in the bore of the closure head.
A modified form of closure head assembly HC is shown in FIGURES 3 and 3A. In this form of the device, a removable cylindrical sleeve 0r cartridge C is disposed within the bore of the closure head body 220, and the vertical flow passages 231 and 232 are formed in the sleeve.
In this form of the device, the outer body 220 of the closure head assembly HC may be substituted for the outer casing hanger 14, and may have the outer casing string 13 connected to its threaded lower end 221 by the coupling 2210!. The body is therefore substituted for the outer casing hanger 14, and the outer body 220 thus becomes a part of the casing head assembly and functions as the outer casing or production hanger 14.
The lower portion of the bore 225 of the body 220 is provided with internal annular recesses therein for receiving the locking dogs 21 and 22 of the casing hangers 19 and to support the casing strings 17 and 18 in the manner first described. Thus, the outer body 220 of the hanger assembly HC remains fixed in place on the well head, while the cylindrical sleeve or cartridge C is removable from within the bore of the body 220.
Latch means 222 are provided exteriorly adjacent the upper end of the body and lock the same in the outer hanger or in the same manner as the outer casing hanger 14' first described. Lateral flow Wings 250 and 250a are formed on the body 220 and project laterally therefrom as shown in FIGURE 6. While two flow wings are shown, it is obvious that only one may be used, if desired. An arcuate lateral flow passage 251 is formed in the wing 250 and a similar arcuate lateral flow passage 25001 is formed in the flow wing 250a. It is to be understood, of course, that the flow passage 2510 may be formed in the wing 250 if desired, and extend laterally to the coupling C in the same manner as the flow passages 51 and 52 of the form first described.
The cylindrical sleeve or cartridge C is removably anchored in the bore 225 of the body 220 by locking dogs or lugs 226 and a locking sleeve 227 at the upper end of the cartridge. Such a locking mechanism is shown in the patent to Raulins, 3,090,438, issued May 21, 1963. The dogs 226 prevent upward movement of the sleeve within the bore of the body 220 while the lower beveled end 228 of the sleeve engages a shoulder at the upper end of the production casing hanger 20, which is locked in place in the lower portion of the bore 225 of the closure head outer body, and is held thereby against downward movement in the outer body.
The inner cylindrical sleeve cartridge C includes the body 230 having bores 231 and 232 formed therein for receiving the flow control devices or valve assemblies 55 and 56 in the same manner as the form first described. The tubing strings 33 and 34 are connected by screw threads (not shown), in the lower portions of the bores 231 and 232 in the same manner as the form first described. Also, if desired, the lower portion of each of the bores 231" and 232 may be provided with an internal annular beveled seat 240 and an enlarged seal bore 241 thereabove for receiving and supporting a hanger head or coupling 242 to which the upper end of the tubing string 33 is threaded, as shown in FIGURE 3A. The hanger member or head 242 has an external annular recess and a seal ring 244 is disposed in the recess and seals v between the coupling and the bore wall 241. The lower portion of the head or hanger member is provided with a beveled shoulder 245 which engages the upwardly facing shoulder 240 to support the tubing string. The lower portion of the bore 241a below the shoulder is sufliciently large to pass the couplings and other protuberances on the string 33 below the hanger. The length of the hanger 243 is such that its upper end 248 is disposed to be engaged by the lower end of the flow controlling valve assembly 55, as shown in FIGURE 3A, whereby the hanger is securely held in place in the bore 241 and cannot be displaced upwardly therefrom, being locked in place by the locking mechanism of the valve assembly.
The body of the inner sleeve or cartridge C is provided with lateral openings or apertures 270 and 271 which are arranged to be disposed in alignment and in flow communication with the lateral passages 251 and 251a in the flow wing 250 and the flow wing 250a. Also, the lateral openings 270 and 271 are arranged to communicate and be disposed in alignment with the arcuate flow diverting passages 81 and 81a in the valve assemblies 55 and 56, so that fluid flowing from the tubing strings 33- and 34 will go through the valve assemblies and through the arcuate flow diverter head passages 81 and 81a, then through the openings 270 and 271 into the lateral flow passages 251 and 251a in the flow wings.
A seal ring 301 is disposed in a suitable recess on the exterior of the inner sleeve 230 above the uppermost lateral flow opening 271, a second seal ring 30-2 is disposed in a suitable recess in the exterior of the sleeve between the uppermost lateral opening 271 and the next higher lateral opening 270, and a similar seal ring 303 is disposed in a suitable recess in the exterior of the body 230 below the lateral opening 270. The seal rings 301, 302, and 303 seal between the inner body 230 of the cartridge C and the bore of the outer closure head body 220, whereby fluids flowing through the lateral openings 270 and 271 in the cartridge are directed into the appropriate lateral flow passages 251 and 251a.
Additional lateral arcuate flow passages may be provided in the flow wings 250 and 250a, and apertures communicating therewith sealed in the same manner to provide "four passages, as shown in FIGURE 6. In such case, the passages would be spaced longitudinally in order that seal rings such as the seal rings 301, 302, and 303 may be disposed therebetween to direct fluids into such lateral flow passages.
The lateral apertures 270 and 271 of the cartridge are oriented into alignment with the lateral flow passages 251 and 251a by means of a camming surface 310' formed on the lower exterior portion of the cartridge body 230 and engaging an orienting leg 311, shown in dotted lines in FIGURE 3, whereby the inner sleeve or cartridge C is turned about its longitudinal axis to the correct position to dispose the lateral apertures 270 and 271 in alignment and flow'communication with the lateral arcuate passages 251 and 251a in the flow wings.
Threads 231a and 2320 are formed in the upper portions of the bores 231 and 232 in the inner sleeve and provide means for coupling lubricators or the like to the sleeve in fiow communication with the bores in the sleeve in the same manner as with the passages of the form first described.
An internal annular groove 229 is formed in the upper portion of the locking sleeve 227 on the body 230 for engaging by suitable running and retrieving tools whereby the locking sleeve 227 may be actuated to lock and release the dogs 226 to effect insertion and removal of the cartridge C in the outer body 230 of the closure head assembly.
The neck 233 at the upper end of the outer body is provided with an external annular flange 219, similar to the flange 119 of the head first described, by means of which blowout preventers and similar devices may be connected to the upper end of the outer body 230. Also, the flange and the annular groove 219a formed therebelow functions in the same fashion as the groove 120 to receive the locking dogs or detent fingers of the lubricator devices R, or cap in the manner already described in connection with the form first described.
Longitudinally spaced annular grooves 320 and 321 are formed in the exterior of the sleeve 220 andseal rings 304 and 305 disposed in suitable grooves on the exterior of the body 230 seal between the body and the closure member 220, so that operating fluid from the lines 299 and 298 may be directed into the flow controlling valve assemblies to operate the valves in the manner already described.
The valve assemblies disposed in the longitudinal bores 230 and 231 are identical to those first described and function in the same manner, being removable through lubricator from the vertical bores 231 and 232 in the manner already described.
It will now be seen that this modified form of the device provides for a permanent lateral flow wing installation including an outer body and a removable inner sleeve or cartridge, carrying the tubing strings therewith disposed in the outer body and insertable and removable therefrom without disturbing the lateral flow installation. Also, it will be seen that this form of the device provides for separate removal of the tubing strings, if desired, by use of the tubing hanger member 242 for supporting the tubing strings 33 and 34.
The inner sleeve or cartridge is properly oriented Wit respect to the lateral flow passages by the orienting cam surface 310 and the lug 311, while the valves are oriented in their relationship to the passages by the cam surfaces 91 on the valves and the lugs 92 in the bores 230 and 231, so that a continuous flow passage is provided from the tubing strings through the arcuate diverter passages in the valve assemblies to the lateral flow lines F1 and F2. It is also believed readily apparent that the valve assemblies may be removed from the cartridge for access to the tubing, and, if desired, the tubing strings themselves may be each individually removed, or both removed, leaving the sleeve or cartridge in place, or that the cartridge may be removed lifting the tubing strings therewith. If desired, the valves may be left in place in the longitudinal bores in the inner sleeve or cartridge while lifting the cartridge and the tubing strings supported therewith.
The foregoing description of the invention is explanatory only, and changes in the details of the construction illustrated may be made by those skilled in the art, within the scope of the appended claims, without departing from the spirit of the invention.
What is claimed and desired to be secured by Letters Patent is:
1. A well head closure assembly for use on a well having a casing therein, including: a body member adapted to be connected in closed relationship to the casing; longitudinal flow passage means in said body member communicating with the casing in the Well; means for supporting a well tubing string in said body member in flow communication with the flow passage means; a lateral flow conductor means on said body member having means for connection to a lateral flow line; and flow control means releasably disposed in said longitudinal passage means of said body member and having means providing a flow directing passage from the bore of the tubing string supported in the body member to the lateral flow conductor means of the body member.
2. A device of the character set forth in claim 1 wherein said flow control means includes: a valve having means operable from a remote point for controlling flow through said flow directing passage of said control means from the tubing to the lateral flow conductor means of the body member.
3. A well head closure assembly of the character set forth in claim 1 wherein said body member includes an outer tubular member having lateral flow passage means formed thereon communicating with the bore of said tubular member; and an inner body member releasably disposed in said outer member in sealed relationship therewith, said inner member having said longitudinal flow passage means formed therein and lateral flow passage means communicating with said lateral flow passage means in said outer tubular member; and means for releasing and locking the inner member in said outer tubular member.
4. A well head closure assembly for use on a well having a casing therein including: a body having means for connecting the same to a well casing; said body having a plurality of longitudinal bores therein; said body having means at one end of each of said longitudinal bores for receiving and connecting a well flow conductor thereto with such well flow conductor opening into said bore when said flow conductor is connected to said body; each of said bores being provided with internal latch groove means engageable by locking means of well flow control devices for releasably securing well flow control devices in said bores; said body having separate flow conductor passages therein communicating with the longitudinal bores therein and disposed for coaction with said well fiow control devices to control flow through said bores and said passages; and internal annular seal surface provided in each of said bores engageable by sealing means of said well devices whereby flow of fluids through each of said bores is directed through .said well flow control devices to the separate flow passage communicating therewith; said body being provided with second latch groove means engageable by running and retrieving tools whereby the body and the flow conductors connected therewith may be lowered and raised by said running and retrieving tools.
5. A well head closure assembly of the character set forth in claim 4 and including: a well flow control device disposed in each of said longitudinal bores and each communicating with one of the separate fiow passages in said body for controlling flow from the flow conductor into the longitudinal bore and through said flow passages of said body.
6. A Well head closure assembly of the character set forth in claim 3 wherein the body includes an outer tubular member adapted to be connected to the well casing, and an inner removable cartridge removably disposed in the outer member and releasably locked in sealed rela tionship therewith, said inner removable cartridge having said longitudinal bores formed therein and provided with flow passages communicating said bores with the flow conductor passages of the outer tubular member of the body.
7. A well head closure assembly of the character set forth in claim 5 including hanger means for removably supporting a well flow conductor in each of said longitudinal bores of said body inflow communication therewith, each said hanger means being removably locked in the bore by the flow control device disposed therein.
8. A well head closure system comprising: an outer body member supported On. a well casing; an inner cartridge member releasably locked within said outer body member, said inner member having flow passage means therein and including remotely controllable valve means for controlling fluid fiow between a tubing string operably connected with said inner member and said flow passage means; means on said inner and said outer member for releasably securing said inner member in said outer member; and lateral flow passage means on said outer member communicating with the flow passage means of the inner member whereby operation of said valve means controls flow through said flow passage means from said tubing string to said outer member.
9. A well head closure assembly of the character set forth in claim 8 wherein the flow passage means of said inner member is provided with means engageable by locking means on said valve means for releasably securing said valve means in said flow passage means of said inner member.
10. A well head closure system of the character set forth in claim 9 including hanger means removably supporting said tubing string in said inner member, said hanger means being locked in said inner member by said valve means.
References Cited UNITED STATES PATENTS 3,064,735 11/1962 Bauer et al. 166-.6 3,102,591 9/1963 Raulins 166.6 3,189,097 6/1965 Haeber 166-.6 3,332,493 7/1967 Jones l6675 3,347,311 10/1967 Word 166-.6 3,353,595 11/1967 Nelson et al. 66-.6
DAVID H. BROWN, Primary Examiner.
US. Cl. X.R. l6672, 89
|Cited Patent||Filing date||Publication date||Applicant||Title|
|US3064735 *||Aug 17, 1959||Nov 20, 1962||Shell Oil Co||Wellhead assembly lock-down apparatus|
|US3102591 *||Aug 14, 1959||Sep 3, 1963||Otis Eng Co||Latch means|
|US3189097 *||Apr 27, 1961||Jun 15, 1965||Shell Oil Co||Underwater dual tubing well completion|
|US3332493 *||Oct 20, 1964||Jul 25, 1967||Cameron Iron Works Inc||Apparatus for guiding a well tool being pumped out of a well into a laterally branching flow line|
|US3347311 *||Aug 19, 1963||Oct 17, 1967||Armco Steel Corp||Underwater well completion|
|US3353595 *||May 22, 1964||Nov 21, 1967||Cameron Iron Works Inc||Underwater well completions|
|Citing Patent||Filing date||Publication date||Applicant||Title|
|US3601190 *||May 15, 1969||Aug 24, 1971||Brown Oil Tools||Well production apparatus with fluid operated valve|
|US3685580 *||Jul 26, 1968||Aug 22, 1972||Vries Douwe De||Dual zone completion system|
|US3771603 *||Apr 13, 1972||Nov 13, 1973||Baker Oil Tools Inc||Dual safety valve method and apparatus|
|US3870101 *||Apr 25, 1973||Mar 11, 1975||Baker Oil Tools Inc||Removable subsea production test valve assembly|
|US4143712 *||Jul 12, 1972||Mar 13, 1979||Otis Engineering Corporation||Apparatus for treating or completing wells|
|US4183404 *||Nov 13, 1978||Jan 15, 1980||Otis Engineering Corporation||Plural parallel tubing with safety joints or release from suspended receptacle|
|US4189003 *||Jan 21, 1974||Feb 19, 1980||Otis Engineering Corporation||Method of completing wells in which the lower tubing is suspended from a tubing hanger below the wellhead and upper removable tubing extends between the wellhead and tubing hanger|
|US6039119 *||Jul 12, 1996||Mar 21, 2000||Cooper Cameron Corporation||Completion system|
|US6547008||Sep 7, 2000||Apr 15, 2003||Cooper Cameron Corporation||Well operations system|
|US6978839 *||Nov 20, 2002||Dec 27, 2005||Vetco Gray Inc.||Internal connection of tree to wellhead housing|
|US7093660||Feb 13, 2003||Aug 22, 2006||Cooper Cameron Corporation||Well operations system|
|US7308943 *||Jul 25, 2006||Dec 18, 2007||Cameron International Corporation||Well operations system|
|US7500524 *||Aug 31, 2007||Mar 10, 2009||Cameron International Corporation||Well operations systems|
|US20030094284 *||Nov 20, 2002||May 22, 2003||Fenton Stephen Paul||Internal connection of tree to wellhead housing|
|US20060272823 *||Jul 25, 2006||Dec 7, 2006||Cameron International Corporation||Well operations system|
|US20080017368 *||Aug 31, 2007||Jan 24, 2008||Cameron International Corporation||Well Operations System|
|DE2652042A1 *||Nov 15, 1976||Apr 20, 1978||Baker Int Corp||Ventil- und aufwaeltigungseinrichtung|
|EP0611874A1 *||Feb 1, 1994||Aug 24, 1994||Cooper Cameron Corporation||Subsea wellhead|
|WO1986001852A1 *||Sep 12, 1985||Mar 27, 1986||Britoil Plc||Underwater well equipment|
|U.S. Classification||166/335, 166/344, 166/72, 166/89.2|
|International Classification||E21B34/00, E21B23/00, E21B23/08, E21B33/03, E21B33/047, E21B34/04|
|Cooperative Classification||E21B23/08, E21B33/047, E21B34/04|
|European Classification||E21B23/08, E21B33/047, E21B34/04|