US3732923A - Remote underwater flowline connection - Google Patents

Remote underwater flowline connection Download PDF

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Publication number
US3732923A
US3732923A US00679858A US3732923DA US3732923A US 3732923 A US3732923 A US 3732923A US 00679858 A US00679858 A US 00679858A US 3732923D A US3732923D A US 3732923DA US 3732923 A US3732923 A US 3732923A
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Prior art keywords
flowline
connection
water
connector
flow
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J Fowler
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Cooper Industries LLC
Rockwell Manufacturing Co
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Rockwell Manufacturing Co
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Assigned to SMITH INTERNATIONAL, INC., A CORP. OF CA reassignment SMITH INTERNATIONAL, INC., A CORP. OF CA ASSIGNMENT OF ASSIGNORS INTEREST. Assignors: MCEVOY OILFIELD EQUIPMENT COMPANY
Assigned to CAMERON IRON WORKS USA INC. reassignment CAMERON IRON WORKS USA INC. ASSIGNMENT OF ASSIGNORS INTEREST. Assignors: SMITH INTERNATIONAL, INC.
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    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
    • E21B43/01—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells specially adapted for obtaining from underwater installations
    • E21B43/013—Connecting a production flow line to an underwater well head

Definitions

  • ABSTRACT A method and apparatus related thereto for remotely connecting flowlines to an underwater wellhead.
  • a connector support cradle is mounted to a well conductor.
  • a guide system is provided to guide into place a 3,481,396 12/1969 Williams 61. a1 ..166/.6 remothly Operable underwater tree, flowline loops, 3,384,169 5/1968 Leonard ..166/.5 and Connector hub which is Connected to the 3,419,071 12 19 3 Williams et 166/6 flowline loops.
  • the tree hub is guided and latched into 2,593,491 4/1952 Saunders et al...
  • Pressure is supplied to the connector Blal'ldlng et a1 through conduits to cause the connector to ealingly 3,363,683 1/1968 Corley et a1.
  • 166/.5 engage the hubs providing fl communication 3,373,807 3/1968 Fischer et al 166/.5 between the tree and flowlines 3,353,595 11/1967 Nelson et a1 ..166/.6
  • Underwater drilling for oil and gas has been practiced for a good many years. However, completing these wells with an underwater wellhead assembly near the ocean floor has become common only in the past few years. Underwater wellhead assemblies offer the advantage of safety from collision by oceangoing vessels and from damage by hurricanes, high winds, and ocean currents.
  • these connectors are hydraulically or pneumatically engageable devices affixed to the production tree which is also remotely engaged in the wellhead. As is the case in any piece of equipment with working parts, occasionally the connectors malfunction and require removal for repair. With the presently known connectors, this requires the removal of the production tree also, which is quite a costly operation.
  • the present invention presents methods and apparatus for remotely connecting underwater flowlines to an underwater wellhead independent of wellhead and flowline installation.
  • support means for connection equipment is lowered along with the well conductor casing in the initial drilling stages.
  • the wellhead, production tree and flow loops attached to a connection hub are remotely guided and lowered into place and installed as completion progresses.
  • the ends of flowlines attached to another connection hub are remotely lowered into position in the support means.
  • a special tool permits a downward force to be applied at such a point in relationship to the flowline ends so that the moment produced by flowline weight is counterbalanced for easier alignment and attachment to the support means leaving a space between the end of the flowline hub and the end of the flow loop or tree hub.
  • a connector is remotely lowered into this space and actuated from a remote power source to engage both hubs providing fluidtight flow communication between the flow loops and flowlines.
  • connection parts which are normally susceptible to malfunction are contained in the connector.
  • the connector independently of the flowlines and wellhead, may be remotely disengaged and removed for inspection, repair, or replacement.
  • the production tree and other wellhead equipment may be removed or worked on without disturbing the flowline or vice versa.
  • the present invention therefore, incorporates the advantages of remote flowline connection without the usual disadvantages of removing either or both the production tree and flowline when connector repair is necessary. It also allows independent placement and removal of both the production tree and flowlines without disturbing the other.
  • FIG. 1 is a schematic view of an underwater wellhead connected to underwater flowlines by a connector in accordance with one embodiment of the invention
  • FIG. 2 is a cut-away perspective view of one embodiment of support means utilized in the invention.
  • FIG. 3 is a vertical sectional view of a latch means employed in the invention.
  • FIG. 4 is a top plan view of a flowline hub which may be used in the present invention.
  • FIG. 5 is a vertical sectional view of the hub shown in FIG. 4 taken along lines 5-5;
  • FIG. 6 is a vertical elevational view of the right end of the hub shown in FIG. 5;
  • FIG. 7 is a representative sectional view of the hub of FIGS. 4 and 5 taken along line 7-7 of FIG. 5;
  • FIG. 8 is a perspective view of one embodiment of a guide frame which may be used in the installation of the present invention.
  • FIG. 9A is an elevational view of the guide frame of FIG. 8 connected to a running tool and a flowline hub similar to the hub shown in FIG. 4;
  • FIG. 9B is an elevational view in section of a flowline joint which may be used in the present invention.
  • FIG. 9C is a vertical cross section of the joint shown in FIG. 98;
  • FIG. 10 is a detailed vertical section of the running tool'shown in FIG. 9A;
  • FIG. 11 is a vertical end view of the tool of FIG. 10 shown in its relationship with a flowline hub and latch means;
  • FIG. 12 is a vertical section view of a joint to be connected between a running string and the guide frame of FIG. 9A;
  • FIG. 13 is an elevational view of the guide frame of FIGS. 8 and 9A connected to one embodiment of a flowline connector of the invention
  • FIG. 14 is an exploded perspective view of one embodiment of a flowline connector for use in the invention.
  • FIG. 15A is a top view, partially in section, of the flowline connector of FIG. 14 shown in a disengaged position;
  • FIG. 15B is a top view in section of the righthand portion of the flowline connector shown in FIG. 15A in a partially engaged position;
  • FIG. 15C is a top view similar to FIG. 15B showing the connector in a fully engaged position
  • FIG. 16 is a vertical section of a portion of the flowline connector, running neck, and tool of FIG. 13 taken along line l616 of FIG. 13;
  • FIG. 17 is an elevational view of a portion of the running neck and tool of FIG. 16 taken along line 1717 thereof.
  • FIG. 1 an underwater wellhead and related equipment is shown for well completion near the ocean floor 1.
  • a conductor casing 2 is shown with a support base 3 welded thereto.
  • a production tree designated generally at 10, is shown lowered into position and remotely connected to the well by remote wellhead connection means 20.
  • remote wellhead connection means 20 Several remote wellhead connection means are available. One is described in U.S. Pat. No. 3,186,486.
  • guide tubes 21 are connected by structural supports 22 to connection means 20. Cables 5 pass through the tubes 21 and initially guide the tree 10 and connection means 20 as they are lowered toward the ocean floor. Bell bottoms 23 provide final alignment as tubes 21 engage guide columns 4. The upper ends of tubes 21 are tapered inwardly to accommodate means for guiding other equipment to be subsequently described.
  • Production tree 10 is a dual completion tree.
  • a single completion or other multiple completion may just as easily be performed with the present invention, the dual tree being used only for description purposes.
  • Production tree 10 includes master valves 11, swab valves 12, diverter valves 13, and a valve selector 14 which is connected to a remote control station to control operation of the various valves shown.
  • a valve selector suitable for such use is described in copending patent application U.S. Ser. No. 587,892 filled by John H. Fowler and David P. Herd on Oct. 19, 1966, and assigned to the assignee of the present application.
  • flow loops 25 Connected to the dual strings of production tree 10 are flow loops 25 with wye valves 26 and cross over valve 27.
  • Cross over valve 27 is normally closed. However, during pigging operations to clean out flowlines it may be opened to allow reversal of flow in flow loops 25 so a pig which has entered the flow loops may be returned to its launching point on shore.
  • connector support cradle 30 which is naturally lowered into place along with support base 3 and conductor 2 during the early stages of drilling.
  • Supported by cradle 30 is connector tree hub 31, connector flowline hub 32, and flowline connector 33.
  • Flow loops 25 terminate in a threaded connection with tree hub 31.
  • Connected to flowline hub 32 are flowlines which are run to production collection facilities on shore or at a platformsome distance away.
  • Connector 33 and hubs 31 and 32 provide flow communication between flowlines 35 and flow loops 25.
  • the cradle 30, hubs 31, 32, and-connector 33 comprise the flowline connection means which will be described in more detail.
  • FIG. 2 a perspective cutout view of the connector support cradle 30 is shown.
  • Base rails 51 and bed plate 52 make up the lower framework.
  • a pair of vertical hub yoke pieces 53 are spaced apart and attached at each end of the cradle to rails 51.
  • a rectangular slot 54 open at the upper end is cut in each yoke piece.
  • Inclined surfaces 55 connect the vertical sides of slot 54 to the upper edge 56 of the yoke pieces.
  • a pair of vertical connector yoke pieces 61 are spaced apart and attached to rails 51 and plate 52.
  • a semicircular cutout presents an upwardly facing curved surface 62. The inner edge of surface 62 is beveled at 63.
  • Lying midway between yokes 61 are channel guide pieces 65, one extending upwardly from each rail 51.
  • Angle iron braces 66, 67, and 68 provide rigidity to the whole cradle assembly.
  • Two hub latch housings are attached to each hub yoke, one on each side of the cradle facing each other.
  • Metal plates 69 are welded to inclined surfaces 55 to protect the latch housings 70, and to aid in guiding hubs 31 and 32 (FIG. 1) into place within cradle 30.
  • FIG. 3 is a detail of the entire hub latch assembly to be mounted in latch housings 70.
  • a portion of hub yoke 53 is shown with latch housing 70 in section.
  • the interior of housing 70 is cylindrical and receives helical spring 71, cylindrical latch shaft 72 and thrust ring 73.
  • Attached to the outwardly facing ends of housing 70 is plate 74 which has a hole slightly larger than the diameter of shaft 72 and concentric therewith.
  • Shaft 72 projects through another hole in the inward face of housing 70.
  • O-rings 75, 76, 77 seal the interior of housing 70 against the underwater environment to which it will be subjected.
  • the end of shaft 72 is provided with a latch key 78 which has an upwardly facing inclined surface 79. In its innermost position, key 78 lies within the projection of slot 54.
  • a rectangular object lowered into slot 54 will contact inclined surface 79 causing key 78 to move back toward housing 70 against the force of spring 71. After the object downwardly passes key 78, shaft 72 will spring back, locking the object into place by virtue of horizontal surface 80.
  • the bottom edge of key 78 has a slight lip bevel 80a to aid in removal of the latched in object on camming key 78 out of engagement as will be more fully understood hereafter.
  • FIG. 4 is a top view of the hub 32. It has cylindrical end portions 81 and 82 connected by a generally square cross section portion 83. Tapped holes 84 are provided for connection of a running and pulling tool to be subsequently described.
  • FIG. 5 a sectional view, it can be seen that four identical guide slots indicated generally at 85 are machined, two each at the junctions of portions 81 and 83 and portions 82 and 83. These slots are formed by dihedral surfaces 86, 87 and 88. (See FIG. 6 also). Guide slots 85 aid in guiding and aligning hub 32 into one pair of hub yokes 53 of cradle 30 (See FIG. 2) which will be better understood subsequently.
  • Dual flow bores 90 and dual hydraulic fluid bores 91 pass longitudinally through the entire length of hub 32. Looking now at FIG. 7, bores 90 and 91 terminate in connection threads 92 and 93 on the outboard end of hub 32. At the inboard end they terminate in counterbores 94 and 95. The opening of each counterbore 94 and 95 is beveled at 96 and 97. Cylindrical portion 81 has an integral locking flange 98 and a frustoconical sealing ring counterbore 99 which communicates with counterbores 94 and 95.
  • Tree hub 31 (FIG. 1) is a mirror image of flowline hub 32 To install tree hub 31 it would be lowered along with the production tree 10, flow loops 25 being connected to the threads on the inboard side (similar to threads 92 described in flowline hub 32). Tree hub 31 can be rigidly attached at the proper location to tree so that it ean be guided into cradle 30 and positioned in rectangular slots 54 of the pair of hub yoke pieces 53(S ee FIG. 2) nearest the well bore at the same time remote connection means 20 engages the wellhead.
  • the guide system including columns 4, tubes 51 and cables 5 provide initial alignment. Final alignment is accomplished by means including the dihedral surfaces 86, 87, 88 of guide slots 85 (FIGS. 4, 5 and 6). If desired, hub 31 will be latched in the cradle by the latch assembly affixed to the yoke pieces 53 or rigidly attached to the well conductor and base.
  • flowline hub 32 requires a special guide frame 100, a perspective view of which is shown in FIG. 8. It includes a triangular'frame 101, guide tubes 102 with bell bottoms 103, a box 104 with a fixed cylindrical passageway 105 therethrough and a running string connection cylinder 106.
  • FIG. 9A an elevational view partially in section, guide frame 100 and running and pulling tool 120 are shown with flowline hub 32 seated in the outboard pair of yoke pieces 53 of support cradle 30 (FIG. 2). Flowlines 35 are connected to hub 32.
  • hub 32 To install hub 32, guide tubes 102 are placed at the water surface around the two cables 5 which are attached to guide columns 4 nearest cradle 30 (FIG. 1). A running pipe string 107 is connectedto cylinder 106 by tool joint 110, to be more fully described subsequently. Running and pulling tool 120 is attached to cylinder 106 at joint 109. Flowline hub 32 is connected to tool 120, which will be more fully described later. Flowlines 35 are connected to hub 32. The whole assembly is then lowered by running string 107 toward the wellhead and support cradle 30. The lowering of flowlines 35 must be coordinated with this operation and may be done from pipeline lay barges or from the drilling vessel itself by use of a plurality of ball joints, to be described later, to impart flexibility to the lines.
  • Flowline hub 32 begins to enter yoke pieces 53 and is guided into final alignment by inclined surface 55 and the dihedral surfaces 86, 87, 88 of guide slots 85 in the bottom of the hub (See FIGS. 4, 5, and 6 Since flowlines 35 are exerting a downward force on the right end of hub 32 (as viewed in FIG. 1) there is a tendency to prevent the left end from properly seating in yoke piece 53. However, since running string 107 is offset to the left endof hub 32 a downward force may be exerted to counterbalance the moment exerted by these flowlines.
  • a flexible joint may be used between flowline sections.
  • a suitable joint is shown in FIG. 9B.
  • the joint comprises three basic parts, socket 185, ball 190, and socket coupling 195.
  • Socket is provided with threads 186 for connection to a flowline section and external threads 187 for connection to coupling 19 5.
  • the internal face of joint 1 185 is machined with a spherically shaped band 188 for mating with ball 19,0. Lying intermediate of band 188 and cylindrical flow passage 189 is frustoconical surface l89a to allow passage of in-line tools, which may .be sent throughflowlines from time to time, even though he axes f 190 a d Sock t 185 re no! ancentrically aligned.
  • Connecting spherical band and surface 189a is a series of radial key slots 18 8a which ma be rm d by mi li in n nn hq ild 1153b a d cyl dr a a 188 e
  • FIQ- Ball 190 has threads 191 for connection to a flowline joint, flow passage 192 and a spherical ball 193 on its inner end.
  • Flowpass'age 192 enlarges through frustoconical portions 19,2a and through the interior of ball 193 to cooperate with surface 189a of socket 185 n allowing o p s a d r n n a i m nt- A p tion of spherical ball 193 mates with socket surface 188, O-ring seal 194 assuring a fluid tight sliding joint. Milling out radial slots 193a between surface and the exterior of spherical ball 193 provides ball 193 with keys which mate withkey slots 188a of socket 185 to prevent relative axial rotation bf ball 190 with respect to socket 185.
  • Coupling 195 threaded at 196 to connect to socket 185 and provided with spherical surface at 197, couples all joint pieces together.
  • Frustoconical surface 198 which has a taper of 5 in one preferred embodiment, limits the deflection of the joint to 5 to assure passage of in-line tools.
  • O-rings 199 along with ball 0- rings 194 and 194b assure a fluidtight sliding junction.
  • a lubricating port a allows jIOll'lt lubrication and packing for trouble-free service.
  • Tool is generally cylindrical in shape. It has a cylindrical interior 121 into which a fishing neck projects through a vertical hole 123 on its lower side.
  • Fishing neck 122 is cylindrical and is. attached by flange 124 and bolts 125 to hub The tapped holes 84 for bolts 125 are shown in FIG. 4.
  • Passing horizontally through neck 122 perpendicular to the axis of hub 32 is a cylindrical pin 126 which projects out of each side of neck 122.
  • vertical slots 127 are machined on interior
  • a frustoconical surface 128 on neck 122 and the upper interior of tool 120 is provided to allow passage of debris which might prevent proper seating of neck 122 in too] 120.
  • Neck 122 is held in tool 120 by a piston assembly which includes piston 130, rod 131, circular plate 132, and fork 133.
  • U shaped fork 1.33 which is attached to plate 132 has a pair of horizontal prongs which pass around neck 122 under the projecting ends of pin 126 to lock hub 32 to tool 120.
  • Piston 130 operates in cylinder 134 to move fork 133 in and out of engagement with neck 122. In the position shown fork 133 is fully engaged. To move the fork and hold it in this position fluid pressure is supplied to cylinder 134 through conduit 135 which forces piston 130 to the right as shown.
  • a yoke rest 140 provides a support for the left end of tool 120.
  • Latch retractors 141 may be provided on the bottom of tool 120 just inside yoke pieces 53 to cam key 78 of the latching means, mounted in enclosures 70, out of engagement with hub 32. Normally, retractors 141 are only used when hub 32 is being removed and would not be installed during running operations.
  • Connection elbow 142 and collar 143 are nonrotatingly connected through joint 109 (See FIG. 9A) to the guide frame 100.
  • the axis of collar 143 is the direction of force applied through the running string to counterbalance the moment resulting from the weight of the flowline at the outboard end of hub 32.
  • Tool joint 110 (See FIG. 9A) can be more fully understood with reference to FIG. 12, which shows the joint 110 connected to guide frame cylinder 106.
  • Tool joint 110 is made up of an upper cylindrical portion 150, an intermediate cylindrical portion 151, and a lower cylindrical portion 152 of decreasing diameters.
  • Upper portion 150 is provided with means such as internal threads 154 for connection to running string 107 (See FIG. 9).
  • Joint 110 is connected to cylinder 106 by threads 155 and has a conduit 156 which, in the position shown, communicates with port 157 drilled in cylinder 106.
  • Halfdog set screws 159 aid in aligning joint 1 in this position by running shoulder 160 of the joint back up against the set screws.
  • joint 110 is held in this position by shear screw 158.
  • Port 157 is connected by an external conduit 157a to port 135 in tool 120 (See FIG. 10).
  • fluid pressure may be applied to the left side of piston 130 through the running pipe string.
  • tool joint 110 is screwed further down into cylinder 106 by applying torque to the running string to first shear screw 158 and then turning the running string. Joint 110 will bottom up in cylinder 106 so that conduit 156 now communicates with cylinder port 161 which is connected by another external conduit 161a to port 136 (FIG. 10) on the rod side of piston 130. Bleed port 162 and vent 163 prevent pressure build up under the lower portion of joint 110. Fluid pressure may now be applied from the surface through the running string and joint 110 to release tool 120 from hub 32, as previously explained with reference to FIG. 10. To pull hub 32, the external conduits 157a, 161a would be interchanged so that port 157 is connected to port 136 in tool 120, and port 161 is connected to port 135. The same procedure described for running operations would then be used for pulling operations.
  • FIG. 13 For running connector 33, the same guide frame shown in FIGS. 8 and 9 is used. However, tool 120, tool joint and running string 107 shown in FIG. 9 are removed. Instead, a rotating union 300 is installed in the cylindrical passageway through box 104. Running string 107 is now connected by a conventional threaded connection to union 300. Connected to the lower end of union 300 is connector running and pulling tool 320, which is connected also to running neck 203. Running neck 203 is fastened to running sleeve 202, a portion of connector 33. A full description of running and pulling tool 320 and running neck 203 will follow.
  • connector 33 With connector 33 attached through tool 320 to guide frame 100 and running string 107 at the water surface, rotating union 300 is shear pinned at 300a to prevent rotation of connector 33, and the whole assembly is lowered toward the underwater wellhead and cradle 30, to position connector 33 for engagement with tree hub 31 and flowline hub 32 (See FIG. 1).
  • Guide cables 5, guide tubes 102, and running string 107 provide initial guidance.
  • As bell bottom 103 reaches tube 21 further alignment is attained which is also aided by running sleeve 202 entering guide channels 65, attached to cradle 30.
  • Final alignment is accomplished by connector yoke pieces 61, retainer ring 229 and the beveled ends 240 of cylinder 200. In this fully supported and aligned position connector 33 may be engaged and disengaged with hubs 31 and 32 as described hereafter.
  • FIG. 14 an exploded view, the components of connector 33 may be seen.
  • the exploded pieces to the left of piece 210 are typical of the pieces which lie in an opposite manner to the right of piece 210.
  • Connector 33 comprises a cylinder 200 surrounded by annular running sleeve 201 which has a flange portion 202 for connecting to running neck 203 with bolts 204.
  • Running neck 203 and its function will be subsequently described.
  • Three vertical holes 205 are drilled through flange 202 and cylinder 200 to receive fluid nipples 206.
  • O-rings 207 and 208 seal around flange 202 and nipples 206 respectively.
  • Nipple receptacle 210 has a circular flange portion 211 with smaller diameter hub portions 212 projecting from each side. Three holes 213 are drilled in rib 211 so that they will line up with holes 205 in sleeve 201 when receptacle 210 is centered inside of cylinder 200. Tapped radial holes 209 are provided in sleeve 201 and cylinder 200 to communicate with flat bottom radial holes 214 in rib portion 211. Half dog set screws 200 may then be inserted to affix sleeve 201, cylinder 200 and receptacle 210 to one another. A pair of flow bores 215 and a pair of hydraulic fluid bores 216 pass longitudinally through receptacle 210. Pressure conduits 217 also pass through receptacle 210. Each one of these conduits 217 is in communication with one of the outside holes 213. Middle hole 213 is in communication with pressure conduit 218 which passes through flange portion 211.
  • connector 33 Other components of connector 33 include tube retainer plate 222, pressure ring 223, a set of latch keys 224, latch cylinder 225, a pair of flow tubes 226, a pair of hydraulic tubes 227, and a pair of pressure tubes 228. Also included is retainer ring 229, ram 230, seal ring 231, various bolts, nuts, and O-rings for sealing.
  • FIGS. A, 15B and 15C top sectional views, which show connector 33 seated on connector yoke pieces 61. Tree hub 31 and flowline hub 32 are latched in place within the support cradle. Channel guide pieces 65, previously described, are also shown.
  • Connector cylinder 200 lies between yokes 61 abutting the inner face of each yoke.
  • the ends of cylinder 200 are beveled at 240, cooperating with yoke bevels 63 to aid in alignment of connector 33 as it is installed.
  • Each end of cylinder 200 is threaded at 241 to receive retainer ring 229.
  • Retainer ring 229 provides the bearing surface for supporting connector 33 on the curved surface 62 (FIG. 2) of yoke pieces 61.
  • running sleeve 201, cylinder 200, and nipple receptacle 210 are fixedly attached to each other by set screws 220.
  • Running sleeve 201 cooperates with guide channels 65 for initial alignment of connector 33 as it is installed.
  • a latch cylinder 225 is slidingly disposed in cylinder 200 one on each side of receptacle 210.
  • the outside diameter of latch cylinder 225 is slightly less than the inside diameter of retainer ring 229, allowing latch cylinder 225 to slide back and forth within cylinder 200.
  • An annular shoulder 242 is provided to cooperate with retainer ring 229 to retain latch cylinder 225 within cylinder 200.
  • An inner annular lip 243 engages latch keys 244, the function of which will be more fully understood subsequently.
  • Cylindrical ram 230, pressure ring 233, flow tubes 226, tube retainer plate 222 and hydraulic tubes 227 and pressure tubes 228 are slidingly disposed within latch cylinder 225 and receptacle 210.
  • Retainer plate 222 is attached by bolts to ram 230.
  • Annular grooves, such as 244, are machined on the exterior of flow tubes 226, hydraulic tubes 227 and pressure tubes 228, retainer plate 222 being split to facilitate mounting around these tubes at annular grooves 244.
  • the tubes 226, 227 and 228, ram 230, pressure ring 233, and retainer plate 222 are all fixed for movement together.
  • Ram 230 has a flange lip 245 and a frustoconical inner flange surface 246 in which the seal ring 231 is placed.
  • Latch key 224 comprises a shank portion 250, an inwardly projecting lip portion 251, an inwardly projecting foot portion 252, a outwardly projecting heel portion 253, and an outer groove 254.
  • Latch keys 224 are held in position by latch cylinder 225, ram 230, pressure ring 233, and sliding latch ring 255.
  • Ring 255 is spring loaded by compression coil springs 255a, preventing latches 224 from prematurely moving around the outer end of ram 230.
  • Springs 255a are mounted in sockets 2306 drilled in face 230a of ram 230, and over pins 255b attached to ring 255.
  • connector 33 For running and installing connector 33, its components are first positioned as shown in FIG. 15A. In this position all tubes 226, 227 and 228 lie within the face to face dimension between the flange of hubs 31 and 32, preventing interference when lowering connector 33.
  • pressure is applied through center nipple 206 and conduit 218 (FIG. 14) of receptacle 210 into area 260. This pressure forces latch cylinder 225, ram 230, pressure ring 233, latches 224, and tubes 226, 227 and 228 outwardly first to the position shown in FIG. 153.
  • latch cylinder 225 and latches 2324 will continue to react to pressure within area 260. They will continue to move outwardly, compressing springs 255a, until latch lip 251 falls behind locking flange 98, as shown in FIG. 15C, where latch keys 224 will become stationary since latch foot 252 and latch ring 255 are abutting the back of flange lip 245. Continued pressure will move latch cylinder 225 further outward, lip 243 disengaging groove 254 and engaging the inclined surface 260 on the back of lip portion 251. This finally locked position is shown in FIG. 15C.
  • the angles of the inclined surfaces of lip 243 are self-locking, so that pressure may be relieved from area 260 without fear of disengaging latch keys 224.
  • pressure tubes 228 are shorter than tubes 226 and 227. Due to their shorter lengths, pressure tubes 228 do not engage hubs 31 and 32. On full engagement of connector 33 tubes 228 terminate in the area around tubes 226 and 227 enclosed by seal ring 231. As was previously described, one tube 228 at each end of connector 33 communicates with an outer hole 213 in the rib portion 211 of receptacle 210. The other set of pressure tubes 228 communicate with the other outer hole 213. Thus, pressure may be applied through one set of pressure tubes to check for leaks around ring seal 231 and O- ring seals 259 which surround flow tubes 226 and hydraulic tubes 227. The other set of pressure tubes 228 may be used for return of test fluids or to allow circulation around ring seal 231 to displace salt water which may be present.
  • FIG. 16 shows tool 320, running and pulling neck 203, flange 202 on the running sleeve 201, connector cylinder 200, and connector nipple receptacle 210.
  • Neck 203 has a flange portion 301 which is attached to flange 202 by bolts 302.
  • a tubular prong portion 303 extends upwardly from flange 301.
  • the upper end of prong 303 is provided with frustoconical surface 304.
  • Four V-bottom grooves 305 are circumferentially cut on the interior of prong portion 303.
  • Drilled longitudinally through the walls of neck 203 are four holes 306, only two of which can be seen in the drawing, each one communicating through ports 307 with a different groove 305.
  • Three of holes 306 connect with conduits 26 which sealingly engage holes 213 in receptacle 210 for supplying engaging pressure and test fluid to connector 33 as previously described with reference to FIGS. 13 and 14.
  • the fourth hole 306 communicates with port 307 which may in turn be connected by a hydraulic line (not shown) to a port (not shown) in cylinder 200 to supply pressure in area 265 (FIG. 15C) for disengagement of connector 33.
  • prong 303 slidingly receives a groove protection cylinder 308 the lower interior of which accommodates a spring 309.
  • An upper annular shoulder 310 is provided with O-ring 311.
  • the length of groove protector 308 is such that when tool 320 is removed, cylinder 308, being spring biased, will cause O-ring 31 1 to be placed above the uppermost V-groove 305 in prong 303. This will seal the V-grooves 305 against sea water and debris which might plug up the ports.
  • a lower annular shoulder 312 and half dog set screw 313 limit the upward movement of cylinder 308 and prevent it from being lost.
  • a vent hole 308a allows free movement of cylinder 308 by preventing pressure build-up.
  • Tool 320 has a generally cylindrical body and is provided with connection means such as internal threads 321 for connection to union 300. (See FIG. 13). At its lower end, tool 320 has a smaller diameter prong portion 322. A downwardly facing annular shoulder 323 joins prong 322 to the body of tool 320. External threads are machined at 324 to receive cylindrical sleeve 325.
  • sleeve 325 has a frustoconical surface 326.
  • the internal diameter of sleeve 325 is slightly larger than the external diameter of neck prong 303.
  • sleeve 325 has a .I-slot 327 which opens at its lower end to receive a pin 328 which projects outwardly and is affixed to neck prong 303.
  • J- slot 327 and pin 328 To engage tool 320 and running and pulling neck 203, J- slot 327 and pin 328 must be aligned as the sleeve 325 of tool 320 is lowered around prong 303.
  • Frustoconical surfaces 304 and 326 aid in concentric alignment.
  • tool 320 When the upper surface 329 of J-slot 327 contacts pin 328 tool 320 may be rotated until pin 328 engages the closed end 330 of J-slot 327. Naturally there is a limited amount of axial freedom at this point between running neck 303 and tool 320. When the tool 320 is pushed all the way down onto neck 303 it is engaged as shown in FIG. 16. However, when it moves up such that pin 328 is in the bottom of slot 330 the pairs of rings 331a on prong 322 seal off grooves 305 so that the handling lines do not fill up with sea water.
  • Tool prong 322 is provided with circumferential V- grooves 331 which in the fully engaged position mate with the internal V-grooves 305 of neck prong 303.
  • Each one of V-grooves 331 is connected by a port 332 to a separate vertical passage 333 drilled in prong 322.
  • These passages 333 in turn are connected by internal ports 334 to external outlets 335 around the exterior of tool 320.
  • These outlets may in turn be fitted with hydraulic hoses (not shown) which are run to the surface to a pressure source at the working boat or platform.
  • underwater flowlines 35 may be remotely connected to flow loops 25 of an underwater production tree 10.
  • flowline connection means comprising support cradle 30, tree hub 31, flowline hub 32, and connector 33 has been explained.
  • a method of installing the flow line connection means has been described.
  • a unique method of handling the installation of flowlines 35 has also been disclosed.
  • a remote flowline connector may be installed or removed independently of production tree and flowline installation.
  • a method of connecting an underwater production wellhead positioned near the floor of a body of water to an underwater production flowline comprising,
  • a method of installing production equipment at an underwater wellhead positioned near the ocean floor comprising,
  • a method of installing production equipment at an underwater wellhead positioned near the oceanfloor comprising,
  • a method of installing an underwater flowline for connection to an underwater production wellhead positioned near the floor of a body of water comprising,
  • connection means to the end of a flowline
  • connection means acting as a fulcrum on which a portion of said connection means comes to rest, a l i applying a downward force to the end of said connec tion means to cause it to pivot on said fulcrum into fixed engagementwith said support means,
  • connection means guiding a flowline connector downthrough said body of water along said guide connection into register with said connection means and flow exit means extending from said underwater production wellhead,and i i remotely engaging said connection means and said flow exit means with said flowline connector for fluidtight flow communication therebetween and without altering the relative positions of said connection means, and said flow exit means.
  • connection means 12. The method of claimjt) wherein said guiding and said engagement of said connection means is accomplished through remotely operable means, said remotely operable means being remotely disengageable and reengageable with said connection means for subsequent removal thereof.
  • Apparatus for remotely connecting the ends of a pair of conduits submerged within a body of water for fluidtight flow communication therebetween comprising first connection means connected to the end of one of said conduits, second connection means connected to the end of the other of said conduits and in fixed coaxial spaced relationship with said first connection means, and v connector means adapted to be lowered through said body of water between the ends of said first and second connection means and in juxtapositional relationship therewith, said connector means comprising engagement means adapted for remote operation to engage said first and second connection means for fluidtight flow communication therebetween without disturbing said fixed spaced relationship.
  • connection means in fixed relationship with said first and second connection means engageable with said connector means to guide said connector means from above said body of water to said juxtapositional relationship with said connection means.
  • Apparatus for remotely coupling the ends of a pair of conduits submerged in a body of water comprising,
  • connector means engageable with said guide means and adapted to be lowered from above said body of water to a point in juxtaposition with said first and second coupling means, said connector means comprising slidable engagement means, remotely operable to engage said first and second coupling means for fluidtight flow communication therebetween without disturbing the relative positions of said first and second coupling means.
  • said engagement means comprises latch means adapted to engage said first and second coupling means, said latch means lying within the minimum distance between said coupling means before said engagement and being extendable on said engagement to contact a portion of said first and second coupling means in disengageable engagement therewith.
  • Apparatus for remotely connecting underwater production equipment to a wellhead submerged in a body of water comprising,
  • production tree means engageable with said guide means and adapted to be guided thereby into register with said wellhead, said tree means comprising flow exit means,
  • connection means affixed to said tree means and said wellhead for remote connection thereof in fluid flow relationship therebetween
  • second coupling means attached to one end of an underwater fiowline, said second coupling means being engageable with said guide means and adapted to be lowered into stationary juxtapositional relationship with said first coupling means with a space therebetween,
  • first and second coupling means comprise hub-like means with flow passages therethrough and flange means on the adjacent ends of each coupling means.
  • Apparatus for connecting an underwater flowline to a wellhead with flow exit means submerged in a body of water comprising support means affixed near the floor of said body of water in fixed relationship with said wellhead,
  • first coupling means connected in flow relationship with said flow exit means and supported by said support means second coupling means connected to one end of said underwater fiowline in flow relationship therewith, said second coupling means and said flowline end being adapted for lowering through said body of water to a position whereby at least one end of said second coupling means contacts a portion of said support means at a contact point thereon,
  • said second coupling means and said flowline end being adapted to pivot about said contact point into coaxial alignment with said first coupling means leaving a space therebetween, and coupling connector means adapted to be remotely lowered through said body of water independently

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US00679858A 1967-11-01 1967-11-01 Remote underwater flowline connection Expired - Lifetime US3732923A (en)

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US3795115A (en) * 1972-09-05 1974-03-05 Lockheed Petroleum Services Method and apparatus for joining subsea pipelines
US3884448A (en) * 1973-11-19 1975-05-20 Parker Hannifin Corp Coupler
US4175620A (en) * 1977-12-06 1979-11-27 Brown & Root, Inc. Methods and apparatus for anchoring offshore pipeline
US4188050A (en) * 1977-10-25 1980-02-12 Fmc Corporation Remote-controlled flowline connector
US4320804A (en) * 1979-08-06 1982-03-23 Baker International Corporation Subsea test tree
US4329085A (en) * 1978-12-27 1982-05-11 Smith International, Inc. Connection of underwater lines
US4337971A (en) * 1980-08-07 1982-07-06 Halliburton Company Remote connector
US4364433A (en) * 1980-10-15 1982-12-21 Cameron Iron Works, Inc. Remote connection apparatus
US4371291A (en) * 1978-12-27 1983-02-01 Smith International, Inc. Underwater flowline connector
US4426173A (en) 1981-08-27 1984-01-17 Exxon Production Research Co. Remote alignment method and apparatus
DE3312049A1 (de) * 1981-11-02 1984-10-04 Cameron Iron Works, Inc., Houston, Tex. Leitungsverbinder
US4609304A (en) * 1982-10-26 1986-09-02 Alsthom-Atlantique Apparatus for enabling a self-contained submersible module including a length of conduit for connection to a collector to be repetitively put into place and removed
US4625804A (en) * 1985-03-07 1986-12-02 Grady Allen Survey Consultants, Inc. Remotely releasable template and dome
US5494110A (en) * 1991-11-11 1996-02-27 Alpha Thames Engineering Limited Two-part connector for fluid carrying conduits
EP0952300A1 (en) * 1998-03-27 1999-10-27 Cooper Cameron Corporation Method and apparatus for drilling a plurality of offshore underwater wells
US20030145998A1 (en) * 2002-02-06 2003-08-07 Gawain Langford Flowline jumper for subsea well
US20050070150A1 (en) * 2003-09-23 2005-03-31 Williams Alfred Moore Assembly for connecting a jumper to a subsea structure
US20050242512A1 (en) * 2004-04-20 2005-11-03 Flindall Stephen J Sealing device
US20080202760A1 (en) * 2007-02-24 2008-08-28 M.S.C.M. Limited Subsea securing devices
WO2011110950A2 (en) 2010-03-09 2011-09-15 Acergy France Sa Apparatus and method for installing a pipeline structure at sea
US8214993B1 (en) 2009-11-11 2012-07-10 Coastal Cargo Company, Inc. Method and apparatus for removing or reinstalling riser pipes of a riser bundle
US20120241159A1 (en) * 2011-03-21 2012-09-27 Vetco Gray Inc. Remote Operated Vehicle Interface with Overtorque Protection
US20130249210A1 (en) * 2012-03-26 2013-09-26 Vetco Gray U.K., Limited Quick Disconnect Connector for Subsea Tubular Members
US10060555B2 (en) * 2009-09-16 2018-08-28 Apply Nemo As Load transferring subsea structure
US10119353B2 (en) 2015-12-16 2018-11-06 Fmc Technologies, Inc. Passively locking connector
US11377916B2 (en) * 2020-05-18 2022-07-05 Redhead Services, L.L.C. Polish rod leveling assembly
US11713833B2 (en) * 2012-10-01 2023-08-01 Oceaneering International, Inc. Gravity driven pile tower based device for pipeline lifting and support

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US20140196906A1 (en) * 2012-11-27 2014-07-17 Lane Elenburg Latching system for well swabbing tools
US9341042B2 (en) 2013-06-09 2016-05-17 Richard Machina Stop loss tool for wellheads

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Cited By (48)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US3795115A (en) * 1972-09-05 1974-03-05 Lockheed Petroleum Services Method and apparatus for joining subsea pipelines
US3884448A (en) * 1973-11-19 1975-05-20 Parker Hannifin Corp Coupler
US4188050A (en) * 1977-10-25 1980-02-12 Fmc Corporation Remote-controlled flowline connector
US4175620A (en) * 1977-12-06 1979-11-27 Brown & Root, Inc. Methods and apparatus for anchoring offshore pipeline
US4329085A (en) * 1978-12-27 1982-05-11 Smith International, Inc. Connection of underwater lines
US4371291A (en) * 1978-12-27 1983-02-01 Smith International, Inc. Underwater flowline connector
US4320804A (en) * 1979-08-06 1982-03-23 Baker International Corporation Subsea test tree
US4337971A (en) * 1980-08-07 1982-07-06 Halliburton Company Remote connector
US4364433A (en) * 1980-10-15 1982-12-21 Cameron Iron Works, Inc. Remote connection apparatus
US4426173A (en) 1981-08-27 1984-01-17 Exxon Production Research Co. Remote alignment method and apparatus
DE3312049A1 (de) * 1981-11-02 1984-10-04 Cameron Iron Works, Inc., Houston, Tex. Leitungsverbinder
US4609304A (en) * 1982-10-26 1986-09-02 Alsthom-Atlantique Apparatus for enabling a self-contained submersible module including a length of conduit for connection to a collector to be repetitively put into place and removed
US4625804A (en) * 1985-03-07 1986-12-02 Grady Allen Survey Consultants, Inc. Remotely releasable template and dome
US5494110A (en) * 1991-11-11 1996-02-27 Alpha Thames Engineering Limited Two-part connector for fluid carrying conduits
EP0952300A1 (en) * 1998-03-27 1999-10-27 Cooper Cameron Corporation Method and apparatus for drilling a plurality of offshore underwater wells
US6497286B1 (en) 1998-03-27 2002-12-24 Cooper Cameron Corporation Method and apparatus for drilling a plurality of offshore underwater wells
US6725936B2 (en) 1998-03-27 2004-04-27 Cooper Cameron Corporation Method for drilling a plurality of offshore underwater wells
US20030145998A1 (en) * 2002-02-06 2003-08-07 Gawain Langford Flowline jumper for subsea well
US20030145997A1 (en) * 2002-02-06 2003-08-07 Gawain Langford Flowline jumper for subsea well
US6742594B2 (en) * 2002-02-06 2004-06-01 Abb Vetco Gray Inc. Flowline jumper for subsea well
US7044228B2 (en) * 2002-02-06 2006-05-16 Vetco Gray Inc. Flowline jumper for subsea well
GB2421533A (en) * 2003-09-23 2006-06-28 Dril Quip Inc Assembly for connecting a jumper to a subsea structure
WO2005031110A1 (en) * 2003-09-23 2005-04-07 Dril-Quip, Inc. Assembly for connecting a jumper to a subsea structure
US20050070150A1 (en) * 2003-09-23 2005-03-31 Williams Alfred Moore Assembly for connecting a jumper to a subsea structure
GB2421533B (en) * 2003-09-23 2007-11-21 Dril Quip Inc Assembly for connecting a jumper to a subsea structure
US7318479B2 (en) 2003-09-23 2008-01-15 Dril-Quip, Inc. Assembly for connecting a jumper to a subsea structure
US20050242512A1 (en) * 2004-04-20 2005-11-03 Flindall Stephen J Sealing device
US8011434B2 (en) * 2007-02-24 2011-09-06 M.S.C.M. Limited Subsea securing devices
US20080202760A1 (en) * 2007-02-24 2008-08-28 M.S.C.M. Limited Subsea securing devices
US10060555B2 (en) * 2009-09-16 2018-08-28 Apply Nemo As Load transferring subsea structure
US8732931B1 (en) 2009-11-11 2014-05-27 Coastal Cargo Company, Inc. Method and apparatus for removing or reinstalling riser pipes of a riser bundle
US8214993B1 (en) 2009-11-11 2012-07-10 Coastal Cargo Company, Inc. Method and apparatus for removing or reinstalling riser pipes of a riser bundle
US9849550B1 (en) 2009-11-11 2017-12-26 Coastal Cargo Company, L.L.C. Method and apparatus for removing or reinstalling riser pipes of a riser bundle
WO2011110950A2 (en) 2010-03-09 2011-09-15 Acergy France Sa Apparatus and method for installing a pipeline structure at sea
WO2011110950A3 (en) * 2010-03-09 2012-04-12 Acergy France Sa Apparatus and method for installing a pipeline structure at sea
US8936413B2 (en) 2010-03-09 2015-01-20 Acergy France Sa Apparatus and method for installing a pipeline structure at sea
US8550167B2 (en) * 2011-03-21 2013-10-08 Vetco Gray Inc. Remote operated vehicle interface with overtorque protection
US20120241159A1 (en) * 2011-03-21 2012-09-27 Vetco Gray Inc. Remote Operated Vehicle Interface with Overtorque Protection
GB2501382A (en) * 2012-03-26 2013-10-23 Vetco Gray Inc Quick disconnect connector for subsea tubular members
US9057463B2 (en) * 2012-03-26 2015-06-16 Vetco Gray U.K. Limited Quick disconnect connector for subsea tubular members
GB2501382B (en) * 2012-03-26 2016-01-06 Vetco Gray Inc Quick disconnect connector for subsea tubular members
AU2013201770B2 (en) * 2012-03-26 2017-01-12 Vetco Gray U.K., Limited Quick disconnect connector for subsea tubular members
US20130249210A1 (en) * 2012-03-26 2013-09-26 Vetco Gray U.K., Limited Quick Disconnect Connector for Subsea Tubular Members
US11713833B2 (en) * 2012-10-01 2023-08-01 Oceaneering International, Inc. Gravity driven pile tower based device for pipeline lifting and support
US10119353B2 (en) 2015-12-16 2018-11-06 Fmc Technologies, Inc. Passively locking connector
US11377916B2 (en) * 2020-05-18 2022-07-05 Redhead Services, L.L.C. Polish rod leveling assembly
US20220282584A1 (en) * 2020-05-18 2022-09-08 Redhead Services, L.L.C. Polish rod leveling assembly
US11739598B2 (en) * 2020-05-18 2023-08-29 Redhead Services, L.L.C. Polish rod leveling assembly

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FR1579922A (enrdf_load_stackoverflow) 1969-08-29

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