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Publication numberUS2660248 A
Publication typeGrant
Publication dateNov 24, 1953
Filing dateDec 17, 1951
Priority dateDec 17, 1951
Publication numberUS 2660248 A, US 2660248A, US-A-2660248, US2660248 A, US2660248A
InventorsBrown Cicero C
Original AssigneeBrown Cicero C
Export CitationBiBTeX, EndNote, RefMan
External Links: USPTO, USPTO Assignment, Espacenet
Wellhead apparatus
US 2660248 A
Abstract  available in
Images(3)
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Claims  available in
Description  (OCR text may contain errors)

C. C. BROWN Nov. 24, 1953 WELLHEAD j APPARATUS Filed Dec. 17, 1951 3 Sheets-Sheet l (were C. Brown INVENTOR.

by M1 ATTORNEYJ Nov. 24, 1953 c. c. BROWN WELLHEAD APPARATUS 3 Sheets-Sheet 3 Filed Dec. 17 1951 1 C/ce ro C. Brown Patented Nov. 24, 1953 UNITED STATES ATENT OFFICE WELLHEAD APPARATUS Cicero Brown, Houston, Tex. Application December 11 1951, Serial No. 262,014

14 Claims. 1

This invention relates to new and useful improvements in well head apparatus.

One object of the invention is to provide an improved well head apparatus which is so constructed that the well tubing which is suspended from the apparatus may be either rotated or moved longitudinally, as conditions require, whereby various well operations and the setting of well tools ma be accomplished after the tubing has been landed.

An important object of the invention is to provide an improved well head assembly for landing and supporting a well tubing string and being arranged so that only metallic seals are exposed to the well pressures when the tubing is in its final position.

Another object is to provide an improved tubing head assembly which includes a swivel mounting for the tubing string whereby a rotative upward tension on the tubing string to obviate leaks at the various couplings and joint connections of the tubing string.

Another object is to provide an improved well head apparatus which is particularly adapted for use in carrying out the well completion method disclosed in my co-pending application, Serial No. 202,174, which method discloses actuation of well tools by means of rotation of the tubing string.

A still further object is to provide an apparatus of the character described which will allow rotation or reciprocation, or both, of the tubing string, after the tubing has been landed and which is constructed so that the tubing may be lowered and landed through the usual blowout preventers and other pressure control equipment, whereby well completion may be carried out with the benefit of blowout protection devices in place, as is the usual practice.

The construction designed to carry out the invention will be hereinafter described together with other features thereof.

The invention will be more readily understood from a reading of the following specification and by reference to the accompanying drawings forming a part thereof, wherein an example of the invention is shown, and wherein:

Figure 1 is a schematic view illustrating the improved tubing head forming part of the present invention and showing the tubing string being lowered within the well through a blowout preventer,

Figure 2 is a similar view showing landing of the tubing hanger,

Figure 3 is a similar View with the blowout preventer and control equipment removed from the tubing head,

Figure 4 is a view similar to Figure 3 showing the lower valve of a Christmas tree assembly connected with the tubing head,

Figure 5 is an enlarged vertical sectional view of the improved well head apparatus illustrating the parts in position after landing of the tubing hanger,

Figure 6 is a view similar to Figure 5 showing the actuating stem moved upwardly with respect to the hanger with a tension pulled on the tubing string, and

Figure 7 is a sectional detail illustrating the manner of removal of the check valve which normally closes the bore of the tubing string during the lowering and landing of said string.

In the drawings the numeral Ill designates a casinghead which is mounted on the last string of easing extending downwardly into the well bore (not shown). A tubing head H provided with a base flange l2 (Figure 5) is bolted to the upper flange of the casinghead and is provided with an axial bore l3 from which the usual side outlets I4 extend. An upper flange I5 is formed on the tubing head body for connection with control equipment during lowering and running of tubing within the well bore. A plurality of radial lock screws it, only one of which is illustrated, are provided in the flange and are arranged to project inwardly into the upper end of the bore of the tubing head body. A sealing plug ll closes the outer end of the open ng in which each locking screw is mounted. The flange also has a radial test port is normally closed by a plug I9. Within the upper portion of the bore 13 of the tubing head is an annular seat 20 which is adapted to receive a hanger assembly generally indicated by the letter A in Figure 5, as will be explained.

The tubing head H is assembled above the casing head i e and as shown in Figure 1, a blowout preventer B is mounted above the tubing head. Above the blowout preventer is usually a second blowout preventer and a master gate valve, neither of which is shown because this is standard blowout prevention equipment. The hanger assembly A includes a tubular stem 21 which has its lower end threaded into a coupling 22 and said coupling is threaded onto the upper end of the tubing string 23. A lowering pipe 2% is adapted to thread into the upper end of the hanger assembly A, whereby the tubing and the hanger may be lowered downwardly through the blowout preventer equipment to engage the seat 28 Within the tubing head II. This lowering operation is clearly illustrated in Figures 1 and 2, the latter showing the hanger assembly seated within the tubing head.

After the assembly is seated the lock screws G are utilized to lock said hanger upon the seat, and as will be hereinafter explained, the tubing bore is closed at this time. is locked down by the lock screws the blowout preventer equipment above the tubing head may be removed and a hold-down flange 25 may be substituted therefor, such hold-down flange being secured to the u per flange l5 of the tubing head by bolts 26. Thereafter the lowering pipe 24 is removed from the hanger assembly and the usual Christmas tree is then connected with the flange 25, as clearly shown in Figure 4. The entire Christmas tree is not shown since this is standard ecuipment and onl the lower valve '25 of said Christmas tree is illustrated. The connection between the Christmas tree and the flange 25 may be made through the usual flanged riser 21. i

The particular hanger assembly A is clearly shown in Figures 5 and 6 and includes a hanger body 28 having an inclined seating surface 29 which is adapted to engage the annular seat 28 within the tubing head. Suitable packing rings 30 which may be the usual O-ring type of packing are mounted in external grooves in the seating surface 29 and function to effect a pressure type seal at this point. An annular groove 3! is formed in the hanger body and when said hanger is in a seated position this groove is opposite the locking screws I5 whereby said screws may be moved inwardly into engagement with the groove to thereby lock the body against upward displacement. When the hanger body is seated the groove 3! is also opposite the test When the hanger port l8 so that a testing of the seals may be effected in the usual manner.

The hanger body 28 is formed with an integral depending extension 32 and said extension has its bore recessed to receive chevron type packing 33 which is retained in place by a flanged packing gland 3d.

lower end of the bore of the gland 34 is formed with an inclined annular seating surface 37.

The tubular stem 2! which forms part of the hanger assembly extends downwardly through the hanger body and the extension, as well as through the packing gland 34, and has the coupling 22 secured to its lower end. The upper end of the coupling 22 is formed with an inclined surface 33 which is adapted to engage and seat within the lower end of the gland 34, the surface 38 contacting and maintaining sealing engagement with the seat 31 of said gland.

For imparting a rotative movement or a longitudinal movement or both to the sealing stem 2 to impart similar movement to the tubing 23, the upper portion of said stem is enlarged and provided with coarse threads 39 which may be An O-ring type packing 35 is mounted within a suitable groove of the bore of either left or right hand threads. Above the threads the stem is formed with a flange 86 whereby, if desired, the Christmas tree may be attached directly to the stem instead of to the retaining flange 25. The threads 39 are adapted to interengage with threads 5! formed Within the bore of a rotatable actuating nut 4 2. The threads 4! will of course be in the same direction as the threads 35, and likewise maybe either lef or right hand threads. As is clearly shown in Figure 5, the nut 42 is mounted upon ball bearings 43 which are disposed within a raceway "64 formed in the upper surface of the hanger body 28. Upward displacement of the rotatable actuating nut 42 is prevented by a retaining collar 45 which has its upper end overhanging an external shoulder 46 formed on the nut; the re taining collar is threaded onto the upper end of the hanger body and thereby retains the actuating nut as part of the assembly. A suitable O-ring packing A? seals oil between the retaining collar and actuating nut, while sealing material 48 is interposed between the bore of the nut and the threads of the actuating stem to seal off the thread connection. Two or more recesses 49 may be formed in the exterior of the actuating nut for receiving a spanner wrench to impart rotation to the nut.

When the hanger assembly A is seated within the tubing head, as illustrated in Figure 5, and the blowout preventer equipment has been removed, an additional seal between the hanger body 28 and the tubing head body is effected by a sealing ring 50. This sealing ring is of an inverted U-shape in cross-section and engages within a groove 5! provided in an external shoulder on the hanger body as well as within a groove 52 formed in the upper surface of the tubing body. The flange 25 rests upon the upper surface of the sealing ring 59 and functions to hold the same in sealing position.

In the operation of the apparatus, the hanger assembly A has its tubular stem 2! connected through the coupling 22 with the tubing 23. back check valve 53 (Figures 5 and 7) having an upwardly closing ball check 54 is connected in left hand threads 55 formed within the upper end of the tubular stem 2! of the hanger assembly. This ball check functions to close the bore of the tubing during lowering and landing of the tubing. Right hand threads 56 provided above the threads 55 receive the lower end of the lowering pipe 24.

The tubing head H is mounted on the casing head, as shown in Figure 1, with the blowout preventer equipment mounted thereabove. By means of the lowering pipe 24 the last portion of the tubing 23 and the hanger assembly A are lowered through the blowout preventer until the inclined seating surface 29 of the hanger body 23 engages the seat 2E! of the tubing head. Upon reaching this position the lock screws I 6 are operated to engage the annular groove 3! in the hanger, and thus the hanger is locked down within the tubing head. The hanger functions to seal the annular space between the tubing and the casing while the back check valve 53 closes the bore of the tubing against upward flow. It is thus possible to remove the blowout preventer equipment from above the tubing head and when this is done the sealing ring 5@ is placed in position between the hanger body 28 and the tubing head body; the flange 25 is then bolted in position to the upper flange of the tubing head and thereon which is to be set down the hole to pack off between the tubing andthe casing in the usual manner, and such packer may be of a con-- struction which will set the same upon a rotation of the tubing string. In order to effect the seating of the packer it is only necessary to impart a simultaneous rotation to the sealing stem 2i and actuating nut 12, this rotation being possible when the actuating nut is abutting the flange Ml of the sealing stem and the nut or stem is turned. in a direction such that the nut and stem tend to thread toward each other. For example, if threads 39 and 4| are right hand threads, the stem 25 is turned to the right or clockwise, or the nut 42 is turned to the left or counter-clockwise to effect the simultaneous rotation of the nut and stem. The simultaneous rotation of the nut 52 and the stem 2! is substantially frictionless since the nut 42 is mounted upon the ball bearings 43. The rotation of the sealing stem 2! with a simultaneous rotation of the actuating nut 42 will impart a rotative movement to the tubing to effect a setting of the packer or to effect the operation of any well tool mounted on the tubing which will be actuated through rotation. At this time there is a metal to metal seal between the hanger body 28 and the seat 29! of the tubing head. Sealing off around the stem 2! is effected by the O-rings 35 and 36, as well as by the chevron packing 33. After the packer or other well tool has been operated through a rotation of the tubing, it is then desirable to pull an upward tension upon the tubing. It has been found that particularly in the case of older tubing such upward tension is necessary to prevent a leakage at the connecting collars of the tubing string. To accomplish the upward movement of the tubing to pull a tension thereon, it is only necessary to rotate the actuating nut 2 with respect to the tubular stem 2!. Such independent rotation of the nut 42 relative to the stem results in the interengaging threads 39 and ll efiecting an upward movement of the stem. The actuating nut 42 is of course held against upward displacement by the retaining collar 45 and when the threads 39 and M are right hand threads, upon a rotation of the nut 42 to the right or clockwise, the coaction between the threads produces an upward travel of the stem. The lower portion of the tubing will, of course, be held stationary by the setting of the packer and the upward movement of the upper end of the tubing will pull a tension on the entire tubing string. Upward movement of the tubular actuating stem 2| continues until the parts assume the position shown in Figure 6, at which time the beveled upper end 38 of the coupling collar 22 engages the inclined seat 31 at the lower end of the gland 34. The engagement of these parts produces a metal to metal seal which seals ofl between the bore of the tubing and the hanger. It is thus apparent that in final position only metal to metal seals are exposed to the well pressures and the difficulties which are encountered due to the ordinary flexible packing being exposed to well pressures are obviated.

After the apparatus has been actuated, the Christmas tree C is connected either to the flange 25, as illustrated in Figure 4, or is connected to the upper flange Ml of the stem 2| of the assembly. As is the usual practice the Christmas tree has a lubricator at its upper end so that a retrieving tool generally indicated at in Figure '7 may be employed for removing the closure 53 from the tubing. The retrieving tool 60 is threaded into the upper end of the valve or closure 53 with a connection being made by right hand threads 6!. Since the threads SI which mount the valve within the stem 2! are left hand threads the tool may be employed to remove the valve or closure, after which the well may be placed on production with control being through the usual Christmas tree and other valved connections.

From the foregoing it will be evident that a simple and effective type of well head apparatus is provided. The unit is so arranged that it may be lowered and landed through the usual control equipment in accordance with general practice; after the hanger assembly is in place the apparatus may be manipulated to impart a rotation to the tubing or to impart longitudinal movement to the tubing so that any of the well known type of well tools may be set within the well casing. After setting, an upward longitudinal movement of the tubing may be carried out to pull and maintain a tension on the tubing string. The sealing arrangement of the assembly is such that only metal to metal seals are exposed to the well pressure so that the difiiculties encountered with exposure of flexible packing to such pressures are eliminated. V The foregoing disclosure and description of the invention is illustrative and explanatory thereof and various changes in the size, shape and materials, as well as in the details of the illustrated construction may be made, within the scope of the appended claims, without departing from the spirit of the invention.

Having described the invention, I claim:

1. A well head apparatus including, a tubing head, a hanger assembly supported within said tubing head and including a hanger body seated in said tubing head, means forming part of said hanger assembly depending from said hanger body and connected with a well tubing for suspending said tubing, and means for mounting saidlast named means for rotation and longitudinal movement of said well tubing with respect to the hanger body.

2. A well head apparatus including, a tubing head, having a supporting seat, a hanger engageable with and supported upon said seat, a tubular stem element mounted within the hanger and having its lower end depending therefrom and connected with a well tubing, and means for mounting the tubular element for rotation and longitudinal movement of said well tubing with respect to the hanger.

3. A well head apparatusincluding, a tubing head, having an annular seat within its bore, a tubular hanger having an external seating surface engageable with said seat, whereby the hanger is supported within the head, means extending laterally through the head and adapted to engage the hanger for locking said hanger in seated position within the head, a tubular stem extending axially through the hanger and having its lower end connected with a well tubing, and means mounting the tubular stem for rotation and axial movement of said well tubing with respect to the hanger and tubing head.

4. A well head apparatus including, a tubing head, having an annular seat within its bore,

a tubular hanger having'an externallseating surface engageable with said seat, whereby the hanger is supported within the head, means extending laterally through the head and adapted to engage the hanger for locking said hanger in seated position within the head, a tubular stem extending axially through the hanger and having its lower end connected with a well tubing, an annular actuating member surrounding the stem and rotatably mounted on the upper end of the hanger, and interengaging means on the actuating member and stem for imparting longitudinal movement to said stem upon a rotation of said member.

5.. A well head apparatus including, a tubing head, having an annular seat within its bore, a tubular hanger having an external seating surface engageable with said seat, whereby the hanger is supported within the head, means extending laterally through the head and adapted to engage the hanger for locking said hanger in seated position within the head, a tubular stem extending axiall through the hanger and having its lower end connected with a well tubing, an annular actuating member rotatably mounted on the upper end of the hanger and surrounding the stem, and interengaging threads on the stem and member whereby rotation of the member independently of the stem imparts a movement to the stem axially of said member and said hanger. 1

6. A Well head apparatus asset forth in claim 5, together with an enlargement on they stem below the hanger and movable into sealingcontact with the lower end of the hanger when the stem is moved to its limit of upward movement with respect to the hanger.

7. A well head apparatus including, a tubing head having an internal seat, a tubular hanger supported upon said seat, an annular actuating member rotatably mounted on the upper end of the hanger, a tubular stem extending through the actuating member and hanger and having its lower end projecting below the hanger and connected with a well pipe, a coarse thread eonnection between the stem and actuating member, whereby rotation of the actuating member moves the stem axially with respect to the hanger and tubing head, and stop means on the upper end of the stem engageable with the upper end of the actuating member when the. stem is at its limit of downward movement, whereby a subsequent rotation of the actuating member in a direction tending to thread the step means toward the actuating member eifects a simultaneous rotation of the member and stem.

8. A well head assembly as set forth in claim 7, together with an enlargement on the stem below the hanger and movable into sealing contact with the lower end of the hanger to seal betwwn the stem and hanger and also to limit the upward movement of the stem.

- '9; A well head apparatus as set forth in claim '7, wherein the tubular hanger is formed with an external seating surface having sealing contact with the seat within the tubing head.

10. A well head apparatus as set forth in claim '7, wherein the tubular hanger is formed with an external seating surface having sealing contact with the seat within the tubing head, and also wherein said stem has an enlargement thereon below the hanger which enlargement is movable into sealing contact with the lower end of the hangerto seal between stem and hanger and also to limit the upward movement of the stem.

11. A well head apparatus as set forth in claim '7, together with radially extending locking means mounted within the tubing head and engageable with the hanger for locking said hanger on the seat within the head.

12.A well head apparatus including, a tubing head having an internal seat, a tubular hanger havingan external seating surface adapted to engage the seat with sealing contact, an annular actuating member rotatably mounted on the upper end of the hanger, a sealing ring between the upper end of the hanger and the tubing head sealing the joint therebetween, a retaining flange secured to the upper end of the tubing head engaging the sealing ring to retain it in position, a tubular stem extending axially through the actuating member and hanger and having its lower end connected to a well pipe, and coarse interengaging threads between the member and stem whereby rotation of the member imparts longitudinal movement to the stem relative to the hanger and tubing head.

13. A well head apparatus as set forth in claim 12, together with a flange on the upper end of the stem adapted to engage the upper end of the actuating member to limit downward movement of the stem with respect to the hanger, and an enlargement on the stem below the hanger'and movable into sealing contact with the lower end of the hanger when the stem is moved to the limit of its upward movement with respect to the hanger.

14. A well head apparatus as set forth in claim 12, together with a closure removably mounted. within the stem, to close the bore of the well pipe to which the stem is connected.

CICERO C. BROWN.

References Cited in the file of this patent UNITED STATES PATENTS Number Name Date 1,896,236 Howard Feb. '7, 1933 1,902,540 Brown Mar. 21, 1933 1,944,840 Humason Jan. 23, 1934 2,134,044 Humason Oct. 25, 1938 2,139,207 Rector Dec. 6, 1938 2,145,844 Brown Feb. 7, 1939 2,157,964 Mueller May 9, 1939

Patent Citations
Cited PatentFiling datePublication dateApplicantTitle
US1896236 *Feb 3, 1931Feb 7, 1933J H Mcevoy & CompanyRetractable tubing head
US1902540 *Feb 19, 1932Mar 21, 1933Brown Cicero CWell control device
US1944840 *Feb 24, 1933Jan 23, 1934Margia ManningControl head for wells
US2134044 *Jun 22, 1937Oct 25, 1938Humason Granville ATubing head
US2139207 *Nov 30, 1936Dec 6, 1938Rector Laurence LPacking device
US2145844 *Sep 1, 1936Feb 7, 1939Brown Clcero CWell head apparatus
US2157964 *Feb 16, 1934May 9, 1939Mueller Robert ATubing hanger
Referenced by
Citing PatentFiling datePublication dateApplicantTitle
US3011804 *Jul 9, 1956Dec 5, 1961Mcevoy CompanyDual well completion apparatus
US3209829 *May 8, 1961Oct 5, 1965Shell Oil CoWellhead assembly for under-water wells
US3259191 *May 5, 1958Jul 5, 1966Mcclintcck Ross ASubsea blowout prevention and landing apparatus
US3528686 *Jun 24, 1968Sep 15, 1970Vetco Offshore Ind IncRotatable casing hanger apparatus
US4862960 *Sep 15, 1988Sep 5, 1989Cameron Iron Works Usa, Inc.Blowout preventer testing apparatus
US5431230 *Sep 27, 1994Jul 11, 1995Rotating Production Systems, Inc.Slant wellbore tubing anchor catcher with rotating mandrel
US6543533Mar 2, 2001Apr 8, 2003Duhn Oil Tool, Inc.Well tubing rotator
US7000888Mar 29, 2004Feb 21, 2006Gadu, Inc.Pump rod clamp and blowout preventer
US7219738Sep 17, 2003May 22, 2007Dril-Quip, Inc.Inner riser adjustable hanger and seal assembly
US7278490 *Dec 28, 2004Oct 9, 2007Stinger Wellhead Protection, Inc.Blast joint swivel for wellhead isolation tool and method of using same
US7789133Mar 20, 2008Sep 7, 2010Stinger Wellhead Protection, Inc.Erosion resistant frac head
US8016031Sep 2, 2010Sep 13, 2011Stinger Wellhead Protection, Inc.Erosion resistant frac head
US8820400Sep 8, 2011Sep 2, 2014Oil States Energy Services, L.L.C.Erosion resistant frac head
US9016362Oct 7, 2004Apr 28, 2015Oil Lift Technology Inc.Polish rod locking clamp
US9322238Mar 12, 2015Apr 26, 2016Oil Lift Technology Inc.Polish rod locking clamp
US9562404 *Mar 10, 2014Feb 7, 2017Titus Tools, Inc.Well tubing hanger adapted for use with power tongs and method of using same
US20050045323 *Oct 7, 2004Mar 3, 2005Oil Lift Technology Inc.Pump drive head with stuffing box
US20060011347 *Sep 17, 2003Jan 19, 2006Drill-Quip, Inc.Inner riser adjustable hanger and seal assembly
US20060137882 *Dec 28, 2004Jun 29, 2006Mcguire BobBlast joint swivel for wellhead isolation tool and method of using same
US20090236090 *Mar 20, 2008Sep 24, 2009Stinger Wellhead Protection, Inc.Erosion Resistant Frac Head
US20100326648 *Sep 2, 2010Dec 30, 2010Stinger Wellhead Protection, Inc.Erosion resistant frac head
US20150041152 *Mar 10, 2014Feb 12, 2015Tracy Earl KlotzWell tool with connectors and adapted for use with power tongs
US20150240594 *Nov 6, 2012Aug 27, 2015Shell Oil CompanyValve for a hydrocarbon well, hydrocarbon well provided with such valve and use of such valve
CN103930647A *Nov 6, 2012Jul 16, 2014国际壳牌研究有限公司Valve for a hydrocarbon well, hydrocarbon well provided with such valve and use of such valve
WO2012009451A1 *Jul 13, 2011Jan 19, 2012Richard WhiteDrilling operation suspension spool
Classifications
U.S. Classification166/78.1, 166/88.4
International ClassificationE21B33/04, E21B33/03
Cooperative ClassificationE21B33/0415
European ClassificationE21B33/04F