US3279536A - Submarine drilling and production head and method of installing same - Google Patents

Submarine drilling and production head and method of installing same Download PDF

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US3279536A
US3279536A US100411A US10041161A US3279536A US 3279536 A US3279536 A US 3279536A US 100411 A US100411 A US 100411A US 10041161 A US10041161 A US 10041161A US 3279536 A US3279536 A US 3279536A
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tubular member
mandrel
production
tubing
outlet
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US100411A
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Jr Charles E Wakefield
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Richfield Oil Corp
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Richfield Oil Corp
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    • E—FIXED CONSTRUCTIONS
    • E21—EARTH DRILLING; MINING
    • E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B33/00—Sealing or packing boreholes or wells
    • E21B33/02—Surface sealing or packing
    • E21B33/03—Well heads; Setting-up thereof
    • E21B33/035—Well heads; Setting-up thereof specially adapted for underwater installations

Definitions

  • a device known as a Christmas tree When drilling into and producing from a stratum containing oil and gas under high pressure, a device known as a Christmas tree is normally utilized to control flow of oil and gas from the well during the .period of natural flow.
  • the Christmas tree comprises an assemblage of valves including generally, a master valve, one or more wing valves, and such flow constricting and gauging devices as may be required in a particular well.
  • the outer casing is normally cemented into the well with the casing spool, the tubing head, the casing head, and the various Christmas tree components connected to the outer casing by bolting flanged fittings thereto. This, of course, requires working access to the well head during installation.
  • FIGURE 1 is an elevation of my underwater production head showing its position relative to the well and submarine drilling base.
  • FIGURES 2a and 2b are divided longitudinal sectional views of the assembled production head showing the outer production mandrel and the inner tubing hanger mandrel assembly.
  • FIGURES 3 through 7 show the steps of the method for installing the production head in a well drilled into a formation underlying a body of water.
  • FIGURE 3 is a side elevation in diagrammatic form showing the manner in which the inner casing is hung preparatory to landing the assembled production mandrel.
  • FIGURE 4 is a side elevation in diagrammatic form showing the production mandrel positioned on the surface casing landing mandrel just above the landing base.
  • FIGURE 5 is a diagrammatic side elevation showing the equipment used to run the tubing into the well.
  • FIGURE 6 is a diagrammatic side elevation illustrating the means used to plug the production mandrel preparatory to bringing-the well in.
  • FIGURE 7 is a diagrammatic side elevation view showing the benthonic well in production.
  • FIGURES 8a and 8b are divided longitudinal sectional views of a modification of the production head shown in FIGURES 2a and 2b employing a second string of tubing with an additional side voutlet communicating therewith.
  • the invention is illustrated as being embodied in an underwater production head 10 which is adapted to be operated remotely either from a land base or a nearby off-shore structure through control lines.
  • the production head 10 serves the purpose of controlling the fiow of gas and oil from the well 14 which function is normally performed by a Christmas tree and well head in land based operations.
  • the assembled production head 10 is installed from a drilling barge 16 so that it can subsequently be remotely controlled from land at the completion of the drilling operation when the top opening is plugged 01f above the tubing outlet.
  • the bore of the production head assembly shown in FIGURE 2 is enlarged to permit drilling operations and the passage of easing therethrough thus obviating the need for separate installation of the production head at the conclusion of the drilling operation.
  • a landing base 18 with a funnel member 20 and a sleeve 22 which guide drilling tools and various well equipment through the landing base is positioned on the ocean floor at the well opening.
  • the lower portion 22b of the sleeve 22 is afiixed to sleeve 22 in such a manner that the joint forms a seat on which the conductor pipe 24 rests as shown in copending application Serial No. 19,722, of William D. Leake, filed April 4, 1960.
  • a surface pipe 26 is equipped with external lugs (not shown) which supports the surface pipe within the conductor pipe 24.
  • the surface pipe 26 is provided at its upper extremity with a landing mandrel 29 onto which the blowout prevention equipment is latched during the drilling operation.
  • the production head 10 includes a production mandrel 30 which is clamped together in two pieces, the lower portion 32 of which may be provided with splines 34 and cemented into the surface pipe.
  • T he production mandrel 10 functions as one piece and can be constructed as one unit, however, as a prevention measure I prefer to divide the outer mandrel into two pieces as shown to facilitate removal of upper part of the mandrel should the need arise after the lower portion 32 has been cemented into the surface pipe.
  • a sealing member 58 is positioned between the production mandrel and the lower splined portion 32.
  • Portion 32 is equipped with a bafile 36 beneath von a wire line.
  • the production mandrel has a latching neck 56 near its upper end onto which the blowout prevention equipment may be latched while the tubing 54 is being run into the well.
  • the production mandrel 30 is provided with a casing outlet 40 and a tubing outlet 42 through which latter outlet the flow of oil and gas from the well 14 is controlled.
  • a casing flow line 44 is provided at the outlet 40 and a casing valve 46 is positioned at the outlet 40 and hydraulically actuated through fluid control lines 47.
  • actuated control valve 50 similar to casing valve 46, and a second spring loaded safety valve 52 held open with hydraulic pressure, which together control the flow of gas and oil from the well through the flow tube 54.
  • the production head has an outer or production mandrel 30 and an inner or tubing hanger mandrel 31 as shown in detail in FIGURES 2a and 2b.
  • Water shut-01f casing 59 is threaded to the lower end of the production mandrel 30 at 33 and the production tubing 54 is threaded into the lower end of the tubing hanger mandrel at 68.
  • An orientation cam 60 inside the production mandrel 30 is adapted to receive orientation lug 62 on the tubing hanger mandrel 31 only in such a manner that the side opening 64 in the tubing hanger v mandrel 31 registers'with the tubing outlet. 42 in the production mandrel 30.
  • the orientation cam Y60 and the lug 62 have been rotated 180 for the ease of illustration.
  • orientation lug 62 has an internal keyway 63 which is aligned with keyway 61 provided in the tubing hanger mandrel 31.
  • a key held in place by set screw 73 is fitted in the aligned keyways 63 and 61 to prevent the orientation lug 62 from rotating relative to the tubing hanger mandrel 31.
  • the tubing hanger mandrel bore 65 is plugged above the side outlet 64 with any suitable means which can be inserted remotely, such as the Otis type S packing mandrel assembly 66 which can be fitted into sealing position
  • the cap 67 of packer assembly 66 can be removed from a second packer 66b added to the packer ,assembly on an extension 69 to seal off tubing outlet 64.
  • Tubing 54 is threaded into a coupling member 68 which in turn is threaded to the lower end of the tubing hanger mandrel 31.
  • the tubing and the tubing hangermandrel are supported within the production mandrel with a'suitable tubing hangermember such as the automatic tubing hanger 70, on internal tapered portion 72 of the production mandrel.
  • the automatic tubing hanger 70 hangs the tubing in the production head automatically without the use of manually tightened ring nuts or locking screws.
  • the hanger, supporting the tubing string seats on a tapered bowl 72 in the tubing head and is locked against upward movement by spring dogs 75. As the hanger 70 enters the production mandrel 30, the spring dogs 75 surrounding the upper part of the hanger are retracted and the hanger slides-down until, as shown in FIGS. 2b and 8b,
  • the dogs spring automatically into the groove or shoulder 75a provided in the production mandrel. Downhole pressure from below the tubing hanger actuates or looks the automatic tubing hanger by moving the packing unit 77 .upward which, in turn, locks the spring dogs securely 4 1 duction mandrel and the tubing hanger mandrel at their tubing outlets.
  • the tubing hanger seals 71 are the primary.
  • Packer cup 79 also serves as a secondary seal behind primary seals 71, to restrict flow between the tubing and casing to the casing outlet 40.
  • Packer cup 79 is supported by a thimble 80 which is supported on the automatic tubing hanger, 70 by a sleeve 82.
  • Packer thimble 84 is supported in place by the safety joint part 86 which is threaded to the tubing hanger mandrel at 87.
  • FIGURES 8a and 8b A variation of the production head is shown assembled in FIGURES 8a and 8b.
  • a macaroni string 122 is supported within the tubing hanger mandrel 31.
  • a tubing hanger mandrel adaptor 124 is threaded to the upper end of the tubing hanger mandrel 31 and has a macaroni hanger 126 threaded therein on which the inner or macaroni string of tubing 122 is hung with a coupling member 130.
  • Packing member 128 seals oflf flow between tubing 122 and the tubing hanger mandrel above the tubing outlet 42, and sealing elements 129 serve as secondary seals.
  • the upper end of the macaroni hanger 126 is socketed similar to the upper end of the head plug 88 and the safety joint 86 so that the tubing hanger mandrel or the macaroni string (122 can be removed on a socket coupling (not shown) attached to the drill string.
  • the upper end 31a of the tubing hanger V mandrel is provided with an additional outlet 132 which communicates with outlet '134 in the production mandrel, thus providing communication between the macaroni tubing 122 and the outlet 120.
  • gas may be injected into the, outlet 120 and through the macaroni tubing to effect a gas lift.
  • FIG. 8a the tubing outlet 42 is shown in phantom since in this modification outlet 42 would not be in the same plane with the casing outlet 40 and macaroni outlet 120.
  • the production head apparatus below the tubing outlet 42 would be essentially the same. asin the production head described above.
  • the production mandrel. is first landed on the surface casing landing mandrel with a suitable landing sub, then the assembled tubing hanger mandrel with tubing connected thereto is lowered into place on the drill pipe with the socket end of a safety joint attached to the lower end thereof, after which the plug 66 is seton a wire line.
  • a head plug 88 is then lowered on the socketend of the safety joint (not shown) and screwed into the production mandrel.
  • the head plug 88 is designed to limit upward movement of the tubing hanger mandrel in the event of a blowout and serves as a secondary seal above packer cup 78 and plug 66.
  • the underwater production head of the present invention is landed at the 'benthos well from a drilling vessel 16 such as is disclosed in detail in copending application Serial No. 19,722, of William D. Leake, filed April 4, 1960.
  • a drilling vessel 16 such as is disclosed in detail in copending application Serial No. 19,722, of William D. Leake, filed April 4, 1960.
  • the blowout prevention equipment 92 latched to the latching neck 28 of the surface casing landing mandrel 29 the lower section of casing 59b is hung on a conventional casing hanger 94 which is lowered into the surface pipe on the drill pipe 96, as shown in FIGURE 3.
  • a suitable release tool 98 is used to release the drill pipe from the casing hanger.
  • a tubing tail 99 is run through the casing hanger and the lower section 59b of the casing is cemented up to the casing hanger.
  • a flexible cement plug 100 is provided to .divide the cement from the drilling mud and a down swab 102 prevents the cement from coming back up the casing.
  • a float collar 101 and -a float shoe103 are provided in the conventional manner at the lower end of the casing to prevent cement from coming back up the inside of the casing after displacement of the cement.
  • the production mandrel 30 with the upper section of casing 590! threaded thereon is lowered into the surface pipe on the drill pipe with a landing sub 110.
  • a suitable casing splice 106 is provided to splice the lower section 5% of the casing to the upper section 59a of the casing.
  • a flexible slip joint 108 may be provided 59a of the casing is cemented through a stage cement collar 112.
  • the casing When the production head is used as a drilling head, the casing is hung from the inside of the enlarged production mandrel, for example, on a donut hanger, and the surface casing is threaded to the lower end of the production mandrel.
  • the blowout prevention equipment 92 is replaced on the production mandrel by latching the blowout prevention equipment to the latching neck 56 of the production mandrel.
  • the casing riser 118 which was used in the drilling operation is then lowered and latched into the upper end of the blowout prevention equipment 92.
  • the tubing is hung on the tubing hanger mandrel and the tubing hanger mandrel lowered into the production mandrel, as shown in FIGURE 5.
  • the socket end 105 of the safety joint is threaded to the drill pipe 96 and releasably latches the safety joint 86 of the tubing hanger mandrel to the drill pipe to lower the mandrel assembly into the well.
  • the lower end of the tubing is provided with a. special packer 114 which is a means of confining zone pressure. Above this packer a sliding side door 116 is provided for circulating mud out of the hole after the tubing is run into the casing.
  • plug 66 with an extension 69 and second packer 66b which seals the bore of the tubing hanger mandrel below the tubing outlet is lowered into the tubing hanger mandrel to seal off the tubing outlet of the tubing hanger mandrel until the mandrel is lowered through the blowout preventers and the tubing outlet put in communication with the tubing outlet valves 50 and 52.
  • the plug 66 is pulled up to the barge and the second packer 66b and extension 69 are removed and a cap 67 screwed into the plug 66 to seal off the tubing above the tubing outlet 64 and permit tubing flow through the outlet.
  • a head plug 88 is then threaded into the production mandrel 30 with the socket end 105 of the safety joint attached to the drill pipe 96.
  • This plug 88 serves as a secondary seal above the packer cup 78 'and also is a secondary seal to the plug 66 as well as a safety device to prevent the tubing hanger mandrel from blowing out of the hole.
  • Flow line 76 is connected to the fail-safe valve 52 and run on the ocean floor with the safety valve control line 49 to a tank (not shown).
  • the casing outlet hose 44 and the remainder of the control lines are then blanked olf and dropped on bottom.
  • a buoy marker is attached to the blanked oif control lines and easing outlet hose as shown in FIG- URE 7.
  • An underwater production head for controlling the flow of oil and gas from a well drilled in a formation underlying a body of water, comprising in combination:
  • said second tubular member having a side outlet in fluid communication with said outlet in said first tubular member
  • first tubular member comprises an upper and lower section and including means for releasably connecting said sections, and means for securing said lower section of said first tubular member into said well.
  • the apparatus of claim 1 including orientation means for registering said side outlet of said second tubular mem- -ber with said side outlet of said first tubular member.
  • the apparatus of claim 1 including a third tubular member supported within said second tubular member, a second side outlet in said first tubular member and said second tubular member, said second side outlet of said second tubular member being in fluid communication with said second side outlet of said first tubular member, said third tubular member having an outlet communicating with said second side outlets of said first and said second tubular members.
  • the apparatus of claim 1 including removable means for sealing the bore below said side outlet of said second tubular member to prevent the flow of oil and gas through said second tubular member side outlet during installation of said second tubular member within said first tu bular member.
  • An underwater production head for controlling the flow of oil and gas from a well drilled in formation underlying a body of water comprising in combination:
  • said second tubular member having a side outlet in fluid communication with said outlet in said first tubular member
  • said second tubular member being so disposed within said first tubular member as to form an annulus between said first and said second tubular members
  • tubing hanger means positioned on said second tubular member below said outlet thereof
  • tubing hanger means being arranged and constructed to support said second tubular member within said first tubular member
  • An underwater drilling and production head for drilling a well in a formation underlying a body of water and subsequently controlling the flow of oil and gas for said well comprising in combination:
  • first tubular member having a side outlet, means for aflixing said first tubular member to said well,
  • said second tubular member being of a smaller outside diameter than the internal diameter of said first tubular member and said second tubular member having a side outlet in fluid communication with said side outlet of said first tubular member,
  • said second tubular member being so disposed within said first tubular memberas to form an annulus between said first and said second tubular member, said second-tubular member having means for supporting tubing therefrom, means for supporting said second tubular member within said first tubular member, and
  • An underwater production head for controlling the cfiowof oil and gas from a well drilledin a formation underlying a body of water, comprising in combination:
  • first tubular member having a side outlet and a shoulder therein, a second tubular member disposed within said first tubular member,
  • said second tubular member having a side outlet in fluid communication with said side outlet of said first tubular member
  • a first tubular member having a side outlet and a shoul-
  • said second tubular member being so disposed within said first tubular member as to form an annulus between said first tubular member and said second tubular member,
  • An underwater production head for controlling the a production mandrel having a side outlet
  • tubing hanger mandrel having a side outlet in fluid communication with said side outlet of said production mandrel
  • tubing hanger mandrel being so disposed within said production mandrel as to form an annulus between said production mandrel and tubing hanger mandrel,
  • An underwater production head for controlling the flow of oil and gas from a well drilled in a formation underlying a body of water, comprising in combination:
  • An underwater production head for controlling the flow of oil and gas from a well drilled in a formation underlying a body of water, comprising in combination:
  • said second tubular member having a side outlet in fluid communication with said outlet in said first tubular member, said second tubular member so disposed within said first tubular member as to form an annulus between said first and said second tubular member,

Description

Oct. 18, 1966 c. E. WAKEFIELD, JR 3,279,535
SUBMARINE DRILLING AND PRODUCTION HEAD AND METHOD OF INSTALLING SAME 4 Sheets-Sheet 1 Filed April 3, 1961 IN V EN TOR. 6 /149455 f. WJKZVEZD, J8
47' TOP/V5 V 1966 c. E. WAKEFIELD. JR 3,279,535
SUBMARINE DRILLING AND PRODUCTION HEAD AND METHOD OF INSTALLING SAME Filed April 5, 1961 4 Sheets-Sheet 2 I 5 I 78 54 \i F E 42 is i s I -64 5?; 666 i {J (2.3 y
80 f z 1 D r Ia 2b,
INVENTOR. e M6, 24. 0 /424555. WAKE/U624].
Oct. 18, 1966 c. E. WAKEFIELD, JR 3,279,536
SUBMARINE DRILLING AND PRODUCTION HEAD AND METHOD OF INSTALLING SAME 4 Sheets-Sheet 5 Filed April 5, 1961 INVENTOR. 67/421555: [4444 5 /52 54 54.21 i iv l 1 3 I'HJH mummy m 1966 c. E. WAKEFIELD, JR 3,279,535
SUBMARINE DRILLING AND PRODUCTION HEAD AND METHOD OF INSTALLING SAME Flled Aprll 3, 1961 1 4 Sheets-Sheet 4 a 6 M; Q L:
INVENTOR. (A 1 7G453 5 WKE HQJQ I BY M 14 7700A/E4 United States Patent 3 279 536 SUBMARINE DRILLING AND PRODUCTION HEAD AND METHOD OF INSTALLING SAME Charles E. Wakefield, Jr., Bakersfield, Califi, assignor to- The present invention is a continuation-in-part of my copending application Serial No. 36,215, filed June 15, 1960, now abandoned, and relates to the production of petroleum from a formation underlying a body of water, more particularly relating to a device for controlling flow of oil and gas from a well underlying a body of water and a method for landing an underwater production head at the ocean floor.
When drilling into and producing from a stratum containing oil and gas under high pressure, a device known as a Christmas tree is normally utilized to control flow of oil and gas from the well during the .period of natural flow. The Christmas tree comprises an assemblage of valves including generally, a master valve, one or more wing valves, and such flow constricting and gauging devices as may be required in a particular well. The outer casing is normally cemented into the well with the casing spool, the tubing head, the casing head, and the various Christmas tree components connected to the outer casing by bolting flanged fittings thereto. This, of course, requires working access to the well head during installation.
In ofi-shore production methods heretofore known the production head has been located at the surface of the water on a platform where workmen can easily flangeup a wellhead and Christmas tree. In deeper water, however, such platforms are obviously impractical and it has been proposed to locate the production head on the floor of the body of water. Installing a conventional Christmas tree on bottom, however, which has been done in some areas, necessarily requires costly diving operations.
It is therefore an object of my invention to provide a novel form of production head for controlling the flow of oil and gas from a well drilled in a formation underlying a body of water and also to provide a method for installing such production head beneath the water surface.
It is also an object of my present invention to provide a submarine production head for installation on the ocean floor at relatively deep depths. It is also an object of my present invention to provide a submarine production head which can be installed remotely from a floating vessel.
It is a further object of my present invention to provide a submarine production head for controlling flow of oil and gas from a location remote from the production head.
It is a further object of my present invention to provide a submarine production head through which drilling operations may be conducted.
Other objects and a fuller understanding of the invention may be had by referring to the fol-lowing description and the appended claims taken in conjunction .with the accompanying drawings, in which:
FIGURE 1 is an elevation of my underwater production head showing its position relative to the well and submarine drilling base.
FIGURES 2a and 2b are divided longitudinal sectional views of the assembled production head showing the outer production mandrel and the inner tubing hanger mandrel assembly.
FIGURES 3 through 7 show the steps of the method for installing the production head in a well drilled into a formation underlying a body of water.
FIGURE 3 is a side elevation in diagrammatic form showing the manner in which the inner casing is hung preparatory to landing the assembled production mandrel.
FIGURE 4 is a side elevation in diagrammatic form showing the production mandrel positioned on the surface casing landing mandrel just above the landing base.
FIGURE 5 is a diagrammatic side elevation showing the equipment used to run the tubing into the well.
FIGURE 6 is a diagrammatic side elevation illustrating the means used to plug the production mandrel preparatory to bringing-the well in.
FIGURE 7 is a diagrammatic side elevation view showing the benthonic well in production.
FIGURES 8a and 8b are divided longitudinal sectional views of a modification of the production head shown in FIGURES 2a and 2b employing a second string of tubing with an additional side voutlet communicating therewith.
With reference to the drawings, the invention is illustrated as being embodied in an underwater production head 10 which is adapted to be operated remotely either from a land base or a nearby off-shore structure through control lines. The production head 10 serves the purpose of controlling the fiow of gas and oil from the well 14 which function is normally performed by a Christmas tree and well head in land based operations. The assembled production head 10 is installed from a drilling barge 16 so that it can subsequently be remotely controlled from land at the completion of the drilling operation when the top opening is plugged 01f above the tubing outlet.
In another embodiment of my invention the bore of the production head assembly shown in FIGURE 2 is enlarged to permit drilling operations and the passage of easing therethrough thus obviating the need for separate installation of the production head at the conclusion of the drilling operation.
Referring now to FIGURE 1 a landing base 18 with a funnel member 20 and a sleeve 22 which guide drilling tools and various well equipment through the landing base is positioned on the ocean floor at the well opening. The lower portion 22b of the sleeve 22 is afiixed to sleeve 22 in such a manner that the joint forms a seat on which the conductor pipe 24 rests as shown in copending application Serial No. 19,722, of William D. Leake, filed April 4, 1960. A surface pipe 26 is equipped with external lugs (not shown) which supports the surface pipe within the conductor pipe 24. The surface pipe 26 is provided at its upper extremity with a landing mandrel 29 onto which the blowout prevention equipment is latched during the drilling operation.
- The production head 10 includes a production mandrel 30 which is clamped together in two pieces, the lower portion 32 of which may be provided with splines 34 and cemented into the surface pipe. T he production mandrel 10 functions as one piece and can be constructed as one unit, however, as a prevention measure I prefer to divide the outer mandrel into two pieces as shown to facilitate removal of upper part of the mandrel should the need arise after the lower portion 32 has been cemented into the surface pipe. A sealing member 58 is positioned between the production mandrel and the lower splined portion 32. Portion 32 is equipped with a bafile 36 beneath von a wire line.
cement returns. The production mandrel has a latching neck 56 near its upper end onto which the blowout prevention equipment may be latched while the tubing 54 is being run into the well.
The production mandrel 30 is provided with a casing outlet 40 and a tubing outlet 42 through which latter outlet the flow of oil and gas from the well 14 is controlled. A casing flow line 44 is provided at the outlet 40 and a casing valve 46 is positioned at the outlet 40 and hydraulically actuated through fluid control lines 47.
actuated control valve 50 similar to casing valve 46, and a second spring loaded safety valve 52 held open with hydraulic pressure, which together control the flow of gas and oil from the well through the flow tube 54.
The production head has an outer or production mandrel 30 and an inner or tubing hanger mandrel 31 as shown in detail in FIGURES 2a and 2b.
Water shut-01f casing 59 is threaded to the lower end of the production mandrel 30 at 33 and the production tubing 54 is threaded into the lower end of the tubing hanger mandrel at 68. An orientation cam 60 inside the production mandrel 30 is adapted to receive orientation lug 62 on the tubing hanger mandrel 31 only in such a manner that the side opening 64 in the tubing hanger v mandrel 31 registers'with the tubing outlet. 42 in the production mandrel 30. In FIGURE 2b, the orientation cam Y60 and the lug 62 have been rotated 180 for the ease of illustration. As best viewed in FIG. 8b,orientation lug 62 has an internal keyway 63 which is aligned with keyway 61 provided in the tubing hanger mandrel 31.
A key held in place by set screw 73 is fitted in the aligned keyways 63 and 61 to prevent the orientation lug 62 from rotating relative to the tubing hanger mandrel 31.
The tubing hanger mandrel bore 65 is plugged above the side outlet 64 with any suitable means which can be inserted remotely, such as the Otis type S packing mandrel assembly 66 which can be fitted into sealing position The cap 67 of packer assembly 66 can be removed from a second packer 66b added to the packer ,assembly on an extension 69 to seal off tubing outlet 64.
Tubing 54 is threaded into a coupling member 68 which in turn is threaded to the lower end of the tubing hanger mandrel 31. The tubing and the tubing hangermandrel are supported within the production mandrel with a'suitable tubing hangermember such as the automatic tubing hanger 70, on internal tapered portion 72 of the production mandrel. The automatic tubing hanger 70 hangs the tubing in the production head automatically without the use of manually tightened ring nuts or locking screws. The hanger, supporting the tubing string, seats on a tapered bowl 72 in the tubing head and is locked against upward movement by spring dogs 75. As the hanger 70 enters the production mandrel 30, the spring dogs 75 surrounding the upper part of the hanger are retracted and the hanger slides-down until, as shown in FIGS. 2b and 8b,
the dogs spring automatically into the groove or shoulder 75a provided in the production mandrel. Downhole pressure from below the tubing hanger actuates or looks the automatic tubing hanger by moving the packing unit 77 .upward which, in turn, locks the spring dogs securely 4 1 duction mandrel and the tubing hanger mandrel at their tubing outlets. The tubing hanger seals 71 are the primary.
seals between the tubing and the casing against upward.
flow through the casing annulus 41 above casing outlet 40. Packer cup 79 also serves as a secondary seal behind primary seals 71, to restrict flow between the tubing and casing to the casing outlet 40. Packer cup 79 is supported by a thimble 80 which is supported on the automatic tubing hanger, 70 by a sleeve 82. Packer thimble 84 is supported in place by the safety joint part 86 which is threaded to the tubing hanger mandrel at 87.
A variation of the production head is shown assembled in FIGURES 8a and 8b. In'this modification a macaroni string 122 is supported within the tubing hanger mandrel 31. A tubing hanger mandrel adaptor 124 is threaded to the upper end of the tubing hanger mandrel 31 and has a macaroni hanger 126 threaded therein on which the inner or macaroni string of tubing 122 is hung with a coupling member 130. Packing member 128 seals oflf flow between tubing 122 and the tubing hanger mandrel above the tubing outlet 42, and sealing elements 129 serve as secondary seals. The upper end of the macaroni hanger 126 is socketed similar to the upper end of the head plug 88 and the safety joint 86 so that the tubing hanger mandrel or the macaroni string (122 can be removed on a socket coupling (not shown) attached to the drill string. The upper end 31a of the tubing hanger V mandrel is provided with an additional outlet 132 which communicates with outlet '134 in the production mandrel, thus providing communication between the macaroni tubing 122 and the outlet 120. As an example of the second recovery techniques for which this macaroni tubing may be employed, gas may be injected into the, outlet 120 and through the macaroni tubing to effect a gas lift.
Packers 136 and 138 (FIG. 8a) are provided above and below the macaroni outlet 120 to seal between the production mandrel 30 and the upper portion 127. of the tubing hanger mandrel. In FIGURE 8b the tubing outlet 42 is shown in phantom since in this modification outlet 42 would not be in the same plane with the casing outlet 40 and macaroni outlet 120. i In the modification shown in FIGURES 8a and 8b the production head apparatus below the tubing outlet 42 would be essentially the same. asin the production head described above.
In operation the production mandrel. is first landed on the surface casing landing mandrel with a suitable landing sub, then the assembled tubing hanger mandrel with tubing connected thereto is lowered into place on the drill pipe with the socket end of a safety joint attached to the lower end thereof, after which the plug 66 is seton a wire line. A head plug 88 is then lowered on the socketend of the safety joint (not shown) and screwed into the production mandrel. The head plug 88 is designed to limit upward movement of the tubing hanger mandrel in the event of a blowout and serves as a secondary seal above packer cup 78 and plug 66.
The underwater production head of the present invention is landed at the 'benthos well from a drilling vessel 16 such as is disclosed in detail in copending application Serial No. 19,722, of William D. Leake, filed April 4, 1960. With the blowout prevention equipment 92 latched to the latching neck 28 of the surface casing landing mandrel 29 the lower section of casing 59b is hung on a conventional casing hanger 94 which is lowered into the surface pipe on the drill pipe 96, as shown in FIGURE 3. A suitable release tool 98 is used to release the drill pipe from the casing hanger.
A tubing tail 99 is run through the casing hanger and the lower section 59b of the casing is cemented up to the casing hanger. A flexible cement plug 100 is provided to .divide the cement from the drilling mud and a down swab 102 prevents the cement from coming back up the casing.
.A float collar 101 and -a float shoe103 are provided in the conventional manner at the lower end of the casing to prevent cement from coming back up the inside of the casing after displacement of the cement.
After the lower section of casing is cemented in the surface pipe the casing is sealed olf internally with a bridge plug or a cement plug 104 and the blowout prevention equipment removed from the well head, as shown in FIGURE 4. The production mandrel 30 with the upper section of casing 590! threaded thereon :is lowered into the surface pipe on the drill pipe with a landing sub 110. A suitable casing splice 106 is provided to splice the lower section 5% of the casing to the upper section 59a of the casing. A flexible slip joint 108 may be provided 59a of the casing is cemented through a stage cement collar 112. Thus the casing and the splined lower portion 32 of the production mandrel are cemented into the surface pipe 26 and surface casing landing mandrel 29. The baflle 36 prevents cement returns from cont-acting the clamp 38. The surface pipe and ,conductorpipe were previously cemented into the well.
When the production head is used as a drilling head, the casing is hung from the inside of the enlarged production mandrel, for example, on a donut hanger, and the surface casing is threaded to the lower end of the production mandrel.
The blowout prevention equipment 92 is replaced on the production mandrel by latching the blowout prevention equipment to the latching neck 56 of the production mandrel. The casing riser 118 which was used in the drilling operation is then lowered and latched into the upper end of the blowout prevention equipment 92. After the casing plug 104 is drilled out or retrieved, the tubing is hung on the tubing hanger mandrel and the tubing hanger mandrel lowered into the production mandrel, as shown in FIGURE 5. The socket end 105 of the safety joint is threaded to the drill pipe 96 and releasably latches the safety joint 86 of the tubing hanger mandrel to the drill pipe to lower the mandrel assembly into the well. The lower end of the tubing is provided with a. special packer 114 which is a means of confining zone pressure. Above this packer a sliding side door 116 is provided for circulating mud out of the hole after the tubing is run into the casing.
Before .the tubing hanger mandrel is lowered through the blowout prevention equipment, plug 66 with an extension 69 and second packer 66b which seals the bore of the tubing hanger mandrel below the tubing outlet, is lowered into the tubing hanger mandrel to seal off the tubing outlet of the tubing hanger mandrel until the mandrel is lowered through the blowout preventers and the tubing outlet put in communication with the tubing outlet valves 50 and 52. After the tubing hanger mandrel 31 is lowered into place, however, the plug 66 is pulled up to the barge and the second packer 66b and extension 69 are removed and a cap 67 screwed into the plug 66 to seal off the tubing above the tubing outlet 64 and permit tubing flow through the outlet. A head plug 88 is then threaded into the production mandrel 30 with the socket end 105 of the safety joint attached to the drill pipe 96. This plug 88 serves as a secondary seal above the packer cup 78 'and also is a secondary seal to the plug 66 as well as a safety device to prevent the tubing hanger mandrel from blowing out of the hole.
At the conclusion of the drilling and cementing operations and after the well is brought in, the drill pipe and casing riser are withdrawn to the barge and the blowout prevention equipment retrieved. The production of fluid from the well is then controlled remotely from a shore control center or a control barge. Flow line 76 is connected to the fail-safe valve 52 and run on the ocean floor with the safety valve control line 49 to a tank (not shown). The casing outlet hose 44 and the remainder of the control lines are then blanked olf and dropped on bottom. A buoy marker is attached to the blanked oif control lines and easing outlet hose as shown in FIG- URE 7.
Although I have described my present invention with a certain degree of particularity in order to set forth the best mode of operation, it is to be understood that my invention is not to be limited to the details set forth but should be given the full scope of the appended claims.
I claim:
1. An underwater production head for controlling the flow of oil and gas from a well drilled in a formation underlying a body of water, comprising in combination:
a first tubular member having a side outlet,
a second tubular member of a smaller outside diameter than the intern-a1 diameter of said first tubular member,
said second tubular member having a side outlet in fluid communication with said outlet in said first tubular member,
said second tubular member so disposed within said first tubular member as to form an annulus between said first and said second tubular members,
means for supporting said second tubular member within said first tubular member,
means actuatable internally of said first tubular member for automatically locking said second tubular member against vertical movement relative to said first tubular member when said second tubular member is supported within said first tubular member by said supporting means, and
means for sealing said annulus above said first and second tubular member side outlets.
2. The apparatus of claim 1 including removable means for sealing said second tubular membersinternally above said side outlet of said second tubular member.
3. The apparatus of claim 1 including means for affixing said first tubular member to said well.
4. The apparatus of claim 1 wherein said annulus sealing means are pressure energized.
' 5. The apparatus of claim -1 wherein said first tubular member comprises an upper and lower section and including means for releasably connecting said sections, and means for securing said lower section of said first tubular member into said well.
6. The apparatus of claim 1 including orientation means for registering said side outlet of said second tubular mem- -ber with said side outlet of said first tubular member.-
7. The apparatus of claim 1 wherein said second tubular member is concentrically disposed within said first tubular member.
8. The apparatus of claim 1 including a third tubular member supported within said second tubular member, a second side outlet in said first tubular member and said second tubular member, said second side outlet of said second tubular member being in fluid communication with said second side outlet of said first tubular member, said third tubular member having an outlet communicating with said second side outlets of said first and said second tubular members. A
9. The apparatus of claim 1 including removable means for sealing the bore below said side outlet of said second tubular member to prevent the flow of oil and gas through said second tubular member side outlet during installation of said second tubular member within said first tu bular member.
10. The apparatus of claim 1 including a second means for sealing said annulus below said communicating side outlets, and
a second side outlet in said first tubular member below said second sealing means, said second side outlet '7 communicating with said annulus below said second sealing. means. 11. An underwater production head for controlling the flow of oil and gas from a well drilled in formation underlying a body of water comprising in combination:
a firs-t tubular member having a side outlet,
a second tubular member of a smaller outside diameter thanthe internal diameter of said first tubular member,
said second tubular member having a side outlet in fluid communication with said outlet in said first tubular member,
said second tubular member being so disposed within said first tubular member as to form an annulus between said first and said second tubular members,
tubing hanger means positioned on said second tubular member below said outlet thereof,
said tubing hanger means being arranged and constructed to support said second tubular member within said first tubular member,
means actuatable internally of said first tubular member for automatically locking said second tubular member against vertical movement relative to said first tubular memberwhen said second tubular member issupported within said first tubular member by said supportingmeans, and
means for sealing said annulus above said first and second tubular member side outlets.
12. An underwater drilling and production head for drilling a well in a formation underlying a body of water and subsequently controlling the flow of oil and gas for said well, comprising in combination: I
a first tubular member having a side outlet, means for aflixing said first tubular member to said well,
means for connecting a surface casing to said first tubular member,-
a second tubular member through which drilling tools may be operated,
said second tubular member being of a smaller outside diameter than the internal diameter of said first tubular member and said second tubular member having a side outlet in fluid communication with said side outlet of said first tubular member,
said second tubular member being so disposed within said first tubular memberas to form an annulus between said first and said second tubular member, said second-tubular member having means for supporting tubing therefrom, means for supporting said second tubular member within said first tubular member, and
means actuatable internally of said first tubular member for automatically locking said second tubular member against vertical movement relative to said first tubular member when said second tubular member is supported within said first tubular member by said supporting means.
16. An underwater production head for controlling the cfiowof oil and gas from a well drilledin a formation underlying a body of water, comprising in combination:
a first tubular member having a side outlet and a shoulder therein, a second tubular member disposed within said first tubular member,
said second tubular member having a side outlet in fluid communication with said side outlet of said first tubular member,
means for supporting said second tubular member within said first tubular member,
means actuatable internally of said first tubular member for automatically engaging said shoulder to lock said second tubular member against upward movement relative to said first tubular member when said second tubular member is supported within said first tubular member by said supporting means, and
means for sealing between said tubular members above said side outlets. 14'. An underwater production head for controlling the flow of oil and gas from a well drilled in a formation underlying a body of water, comprising in combination:
a first tubular member having a side outlet and a shoul-,
der therein,
a second tubular member of a smaller outside diameter than the internal diameter of said first tubular member,
said second tubular member having a side outletin fluid communication with said side outlet of said first tubular member, 7
said second tubular member being so disposed within said first tubular member as to form an annulus between said first tubular member and said second tubular member,
means for supporting said second tubular member with in said first tubular member,
dog means associated with said second tubular member,
means internal of said first tubular member for moving said dog means into engagement with said shoulder automatically when said second tubular member is supportedwithin said'firs-t tubular member by 'said supporting means, to thereby lock said second tubular member against upward movement relative to said first tubular member, and
. means for sealing said annulus above said first and said second tubular member side outlets. 15. An underwater production head for controlling the a production mandrel having a side outlet,
a tubing hanger mandrel of a smaller outside diameter aha? the internal diameter of said production man-,
said tubing hanger mandrel having a side outlet in fluid communication with said side outlet of said production mandrel,
said tubing hanger mandrel being so disposed within said production mandrel as to form an annulus between said production mandrel and tubing hanger mandrel,
means for remotely lowering said tubing hanger mandrel into locking position with said production mandrel from said vessel,
means for supporting said tubing hanger mandrel within said production mandrel, and
means for sealing said annulus above saidside outlets of said production mandrel and said tubing hanger mandrel.
16. The apparatus of claim 15 including a second means for sealing said annulus below said communicating side outlets, and
a second side outlet in said production mandrel below saidsecond sealing means, said second side outlet communicating with said annulus below said second sealing means.
17. An underwater production head for controlling the flow of oil and gas from a well drilled in a formation underlying a body of water, comprising in combination:
9 to said shoulder as said second tubular member is lowered into operative position in said first tubular member.
18. An underwater production head for controlling the flow of oil and gas from a well drilled in a formation underlying a body of water, comprising in combination:
a first tubular member having a side outlet,
at second tubular member of a smaller outside diameter than the internal diameter of said first tubular memher,
said second tubular member having a side outlet in fluid communication with said outlet in said first tubular member, said second tubular member so disposed within said first tubular member as to form an annulus between said first and said second tubular member,
means for supporting said second tubular member within said first tubular member, means for locking said second tubular member in said first tubular member, said locking means including means responsive to pressure in said annulus below said locking means for locking said second tubular member relative to said first tubular member, and
means for sealing said annulus above said first and second tubular member side outlets.
References Cited by the Examiner UNITED STATES PATENTS 1,836,419 12/ 1931 Wigle 16689 X 1,923,448 '8/193-3 McCoy 166-46 2,077,480 4/ 1937 Humason 166-88 2,096,565 10/ 1937 Shaffer et al 16688 2,187,839 1/ 1940 Penick 166 89 X 2,469,772 5/1949 Johnson l6689 2,623,467 12/ 1952 Andrew 166-95 X 2,808,229 10/ 1957 Bauer et al 175-7 2,810,442 10/ 1957 Tausch 16646 X 2,859,823 ll/1958 'Bauer "166-88 2,889,886 6/1959 Gould 166-89 2,906,500 9/1959 Knapp et al 16666.5 X 2,918,972 12/ 1959 Tubbs 16688 2,970,646 2/ 1961 Knapp et al. l6666.5 X 3,032,106 5/ 1962 Focht et al. 16646 3,050,120 8/1962 McSpadden 166--86 X 3,065,792 11/ 1962 Andrew 16 646 3,130,785 4/ 1964 McCullough 166-46 FOREIGN PATENTS 336,323 10/ 1930 Great Britain.
CHARLES E. OCONNELL, Primary Examiner. R. E. FAVREAU, Assistant Examiner.

Claims (1)

17. AN UNDERWATER PRODUCTION HEAD FOR CONTROLLING THE FLOW OF OIL AND GAS FROM A WELL DRILLED IN A FORMATION UNDERLYING A BODY OF WATER, COMPRISING IN COMBINATION: A FIRST TUBULAR MEMBER HAVING A SIDE OUTLET AND A SHOULDER THEREIN. A SECOND TUBULAR MEMBER DISPOSED WITHIN SAID FIRST TUBULAR MEMBER, SAID SECOND TUBULAR MEMBER HAVING A SIDE OUTLET IN FLUID COMMUNICATION WITH SAID SIDE OUTLET OF SAID FIRST TUBULAR MEMBER, MEANS FOR SUPPORTING SAID SECOND TUBULAR MEMBER AGAINST VERTICAL MOVEMENT RELATIVE TO SAID TUBULAR MEMBER, SAID MEANS INCLUDING LOCKING MEANS POSITIONED INTERNALLY OF SAID FIRST TUBULAR MEMBER AND AUTOMATICALLY MOVABLE INTO LOCKING POSITION RELATIVE TO SAID SHOULDER AS SAID SECOND TUBULAR MEMBER IS LOWERED INTO OPERATIVE POSITION IN SAID FIRST TUBULAR MEMBER.
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US3352357A (en) * 1964-11-20 1967-11-14 Shell Oil Co Flexible marine conductor with cellar pipe
US3353596A (en) * 1965-06-30 1967-11-21 Atlantic Refining Co Tubing hanger and method of testing packing thereon
US3602303A (en) * 1967-12-01 1971-08-31 Amoco Prod Co Subsea wellhead completion systems
US5503230A (en) * 1994-11-17 1996-04-02 Vetco Gray Inc. Concentric tubing hanger
US6039119A (en) * 1992-06-01 2000-03-21 Cooper Cameron Corporation Completion system
US20030094284A1 (en) * 2001-11-21 2003-05-22 Fenton Stephen Paul Internal connection of tree to wellhead housing
US6675900B2 (en) 2000-01-27 2004-01-13 David C. Baskett Crossover tree system
US20040140124A1 (en) * 2002-11-12 2004-07-22 Fenton Stephen P. Drilling and producing deep water subsea wells
US6810954B2 (en) 2000-01-27 2004-11-02 Kvaerner Oilfield Products, Inc. Production flow tree cap
US20070289748A1 (en) * 2004-03-29 2007-12-20 Hwces International System and method for low-pressure well completion
US20100006299A1 (en) * 2006-10-04 2010-01-14 Fluor Technologies Corporation Dual Subsea Production Chokes for HPHT Well Production

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US3353596A (en) * 1965-06-30 1967-11-21 Atlantic Refining Co Tubing hanger and method of testing packing thereon
US3602303A (en) * 1967-12-01 1971-08-31 Amoco Prod Co Subsea wellhead completion systems
US7314086B2 (en) 1992-06-01 2008-01-01 Cameron International Corporation Well operations system
US6039119A (en) * 1992-06-01 2000-03-21 Cooper Cameron Corporation Completion system
US6547008B1 (en) 1992-06-01 2003-04-15 Cooper Cameron Corporation Well operations system
US7500524B2 (en) * 1992-06-01 2009-03-10 Cameron International Corporation Well operations systems
US20080017368A1 (en) * 1992-06-01 2008-01-24 Cameron International Corporation Well Operations System
US7093660B2 (en) 1992-06-01 2006-08-22 Cooper Cameron Corporation Well operations system
US7314085B2 (en) 1992-06-01 2008-01-01 Cameron International Corporation Well operations system
US20050155774A1 (en) * 1992-06-01 2005-07-21 Cooper Cameron Corporation Well operations system
US7308943B2 (en) * 1992-06-01 2007-12-18 Cameron International Corporation Well operations system
US20060272823A1 (en) * 1992-06-01 2006-12-07 Cameron International Corporation Well operations system
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US5503230A (en) * 1994-11-17 1996-04-02 Vetco Gray Inc. Concentric tubing hanger
US6675900B2 (en) 2000-01-27 2004-01-13 David C. Baskett Crossover tree system
US6810954B2 (en) 2000-01-27 2004-11-02 Kvaerner Oilfield Products, Inc. Production flow tree cap
US6681852B2 (en) 2000-01-27 2004-01-27 Kvaerner Oilfield Products, Inc. Tubing hanger shuttle valve
US6978839B2 (en) 2001-11-21 2005-12-27 Vetco Gray Inc. Internal connection of tree to wellhead housing
US20030094284A1 (en) * 2001-11-21 2003-05-22 Fenton Stephen Paul Internal connection of tree to wellhead housing
US20060011348A1 (en) * 2002-11-12 2006-01-19 Fenton Stephen P Drilling and producing deep water subsea wells
US7240736B2 (en) 2002-11-12 2007-07-10 Vetco Gray Inc. Drilling and producing deep water subsea wells
US6968902B2 (en) 2002-11-12 2005-11-29 Vetco Gray Inc. Drilling and producing deep water subsea wells
US20040140124A1 (en) * 2002-11-12 2004-07-22 Fenton Stephen P. Drilling and producing deep water subsea wells
US20070289748A1 (en) * 2004-03-29 2007-12-20 Hwces International System and method for low-pressure well completion
US7886833B2 (en) * 2004-03-29 2011-02-15 Stinger Wellhead Protection, Inc. System and method for low-pressure well completion
US20100006299A1 (en) * 2006-10-04 2010-01-14 Fluor Technologies Corporation Dual Subsea Production Chokes for HPHT Well Production
US9051818B2 (en) * 2006-10-04 2015-06-09 Fluor Technologies Corporation Dual subsea production chokes for HPHT well production

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