US3625281A - Well completion method and apparatus - Google Patents

Well completion method and apparatus Download PDF

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Publication number
US3625281A
US3625281A US818726A US3625281DA US3625281A US 3625281 A US3625281 A US 3625281A US 818726 A US818726 A US 818726A US 3625281D A US3625281D A US 3625281DA US 3625281 A US3625281 A US 3625281A
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Prior art keywords
hanger
tubing
riser
connector
casing
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US818726A
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English (en)
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David P Herd
Valoris L Forsyth
James V Bonds
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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
    • E21B33/00—Sealing or packing boreholes or wells
    • E21B33/02—Surface sealing or packing
    • E21B33/03—Well heads; Setting-up thereof
    • E21B33/04—Casing heads; Suspending casings or tubings in well heads
    • E21B33/047—Casing heads; Suspending casings or tubings in well heads for plural tubing strings

Definitions

  • a method and apparatus for completing an underwater well comprising the steps of: lowering hanger means and at least one tubing string on a handling string into the well casing to a position where said hanger means will be supported substantially below the mudline; cementing the tubing string within the well casing by passing cement through the handling string and the tubing string; disconnecting and removing the handling string; lowering connector means, a tubing riser and valve in the casing; and remotely connecting the connector means to the hanger means, placing the tubing string and tubing riser in fluidtight flow communication, the valve being installed in the tubing riser at a point substantially below the mudline, the tubing riser extending to the well platform.
  • One hanger embodiment comprises remotely operable hydraulic slip suspension means which may be activated by a remote pressure source in communication with the suspension means through a handling string and setting tool.
  • the setting tool is provided with latches disengageable from the hanger on rotation of the handling string.
  • One connector means embodiment comprises remotely operable hydraulic latch means which may be activated through a tubing riser to engage the hanger means.
  • An orientation sleeve may be provided on the connector means for aligning the tubing riser and tubing string before engagement.
  • a conduit arrangement is shown which may be used to subsequently disconnect the connector means and riser from the hanger means for removal.
  • This invention pertains to drilling and completion of oil and gas wells. In particular it concerns methods and apparatus for completing a well in relatively deep water.
  • a bottom supported subsea platform be installed with its platform submerged at a depth of around 600 feet.
  • the platform would be equipped to receive a multiple number of remote wellheads and Christmas trees and the necessary manifolds, controls etc. for producing the wells. Drilling operations would be conducted from a floating drilling vessel. Such a platform would not be subject to the wind and wave stress of an above the water platform. Present technology, would allow such an installation.
  • the safety valves might be made inoperative by cement pumped through the tubing string;
  • the tubing string might become stuck before reaching total depth, causing the safety valve to be located above the mudline and preventing the hanger mechanism from reaching the remote wellhead;
  • the present invention eliminates these and other problems by providing a method of completion comprising the steps of: lowering hanger means and at least one-tubing string on a handling string into the well casing to a position where said hanger means will be supported substantially below the mudline; cementing the tubing string within the well casing by passing cement through the handling string and the tubing string; disconnecting and removing the handling string; lowering connector means, a tubing riser and valve in the casing; and remotely connecting the connector means to the hanger means, placing the tubing string and tubing riser in fluidtight flow communication, the valve being installed in the tubing riser at a point substantially below the mudline, the tubing riser extending upwardly to the well platform.
  • Apparatus for performing this method is also disclosed herein including a unique tubing hanger, handling tool and riser connector.
  • a safety valve may be installed below the mudline and in the event of damage to the well platform, the well may be shut-in below the mudline, preventing costly production losses.
  • the valve is not subject to malfunction from cement since cementing is performed before the valve is installed. Should the tubing string become stuck before reaching total depth the hanger apparatus permits the hanger to be installed at several levels and still assures that the valve is below the mudline.
  • the connector apparatus allows removal of the riser and valve subsequent to installation permitting a malfunctioning valve to be repaired or replaced.
  • FIG. 1 is a schematic representation of a submerged platform installation in which a preferred embodiment of the invention might be used;
  • FIG. 2 is a horizontal cross section of a tubing hanger assembly according to a preferred embodiment of the invention taken on line 2-2 of FIG. 3A, primarily for showing where other sectional elevation views are taken;
  • FIGS. 3A and 3B are sectional elevation views of tubing hanger and setting tool apparatus, according to a preferred embodiment of the invention, taken on lines 3A, 3B-3A, 3B of FIG. 2.
  • FIG. 3A being the upper portion
  • FIG. 38 being the continuing lower portion thereof;
  • FIGS. 4A and 4B are elevation views partially in section of the tubing hanger assembly of FIGS. 3A and 3B and a tubing riser connector, according to a preferred embodiment of the invention, taken on lines 4A, 4B-4A, 4B of FIG. 2, FIG. 4A being the upper portion, FIG. 4B the continuing lower portion thereof.
  • FIGS. 5A and 5B are sectional elevation views similar to FIGS. 4A and 4B but taken on lines 5A, SB-SA, 5B of FIG. 2 with a portion of the hanger assembly broken away;
  • FIGS. 6 through 11 are schematic drawings showing the step by step installation of the apparatus shown in FIGS. 2 through 58 with the exception of FIG. 7 which shows a slight variation of the tubing hanger assembly of the embodiment shown in FIGS. 2 through 58.
  • a submerged platform 2 is shown supported at the floor 4 of a body of water 6.
  • the floor 4 may be at a depth of 1,200 feet while the platform level is at a depth of 600 feet.
  • a floating drilling vessel 8 is anchored above platform 2 from which drilling and completion operations take place.
  • the platform 2 is equipped to receive a multiple number of wellheads I0, drilling control equipment 12 and eventually Christmas trees, manifolds, controls etc. (not shown).
  • the drilling control equipment 12 could be installed on the drilling vessel.
  • Guidelines 14 may be attached to the platform 2 for guiding equipment into place.
  • a conductor casing 15 connects the wellhead 10 to the subsea floor 4. Drilling, installation and cementing of surface casing and any intermediate casing strings take place through conductor 15 as in other submerged wells.
  • the well would be completed by the tubingless method.
  • a l6 inch surface casing (not shown) would be installed in 30 inch conductor casing 15.
  • the 10-% inch innermost casing string (not shown) would be installed within this l6 inch surface casing.
  • the dual-tubing strings (not shown) would be run through the control equipment 12 and suspended on a hanger as much as several hundred feet below the level of floor 4 within the l0% inch innermost casing.
  • FIG. 2 is a horizontal section of a portion of a tubing hanger assembly 50 taken on line 2-2 of FIG. 3A and is primarily for the purpose of showing where other sectional views are taken. Shown in this view are dual-tubing run bores 53 and 54, internal port 52, and an alignment dog 51, the construction and purposes of which will be better understood subsequently.
  • FIGS. 3A and 33 a preferred embodiment of the apparatus for suspending dual-tubing strings 21 and 22 in the innermost casing string of an underwater well at a point below the mudline will be described.
  • the apparatus shown comprises a running tool and tubing hanger 50 the upper portion of which is shown in FIG. 3A, the
  • tubing strings 21 and 22 are attached to the bottom of hanger 50 by threaded connections 25.
  • Tubing hanger 50 comprises a generally cylindrical body portion 55 through which pass vertical tubing run bores 54, internal port 52, and cement return bore 76.
  • a half-moonlike slot 77 is cut in the side of hanger body 55 into the upper end of cement return bore 76.
  • slip suspension means comprising mandrel 56, a plurality of slip segments 57, and setting cone 58.
  • the lower end of body 55 has a larger diameter portion 59 and a lower shoulder 60.
  • Shoulder 60 limits the downward movement of setting cone 58 and the larger diameter portion 59 cooperates with a skirt portion of setting cone 58 to provide an annular piston arrangement whereby hydraulic pressure may be applied to the annular space 61 to force setting cone 58 upwardly.
  • Slip segments 57 may be assembled along with setting cone 58 by sliding them down around body 55 before mandrel 56 is installed.
  • Slip segments 57 may be held together by a spring ring (not shown) or the like. After slips 57 are mounted, mandrel 56 may be placed around body 55 and fastened in the mounting position shown by setscrews 64. To prevent premature setting of the slips 57, setting cone 58 may be attached to body 55 by shearpins 65. To set clips 57, a pressure would be introduced into annular space 61 sufficient to shearpin 65 and move setting cone 58 upwardly behind slips 57.
  • the frustoconical surfaces 66 and 67 on setting cone 58 and mandrel 56 respectively, would cooperate with the opposing frustoconical surfaces 68, 69 on the back of slips 57 causing them to be wedged outwardly into engagement with the walls of a surrounding casing (not shown).
  • the weight of the tubing strings 21 and 22 would maintain support engagement even if pressure were relieved from annular space 61. However, with pressure maintained, holddown of the string against down-the-hole pressure would be assured.
  • a receptacle slot is out near the upper portion of hanger body 55 for the mounting of alignment dog 51.
  • the dog 51 is fastened to hanger body 55 by capscrews 70.
  • the upper edge of dog 51 is an inverted V-shape and can best be seen in FIG. 4A.
  • the purpose of alignment dog 51 is to orient apparatus which may be subsequently attached to hanger 50.
  • the upper end of hanger body 55 is provided with pockets 72 and hub shoulder 73 for attachment to tool 80 or any other equipment designed for that purpose.
  • the running too] 80 comprises two latch segments 82 which clamp the running tool 80 to hanger 50.
  • Latch segments 82 comprise a lip portion 83 which engages hub shoulder 73 within pocket 72, a foot portion 84, retained in recess 85 of tool 80 and heel portion 89 for disengagement as will be more fully understood hereafter.
  • Latches 82 are set by sleeve 90 and attached wedge block 91 which are driven down to the position shown by left-hand rotation of couplings 103 and 104 attached to handling strings (not shown).
  • Couplings 103 and 104 are threaded into tool body 86 such as at 92 and communicate with hanger bores 54 through tool body bores 94.
  • a retainer plate 96 is attached to sleeve 90 by capscrews 97, providing annular pockets 99 in which are located bearing shoulders 105 of couplings 103 and 104.
  • One of the bores 94 through tool body 86 is connected to hanger port 52 by internal tool ports 87, nipple 88 and internal hanger port 78.
  • An alignment pin (not shown) projecting out of tool body 86 similar to nipple 88 and a socket (not shown) in hanger body 55 may be provided to aid in alignment of tool 80 with hanger assembly 50.
  • the flow bores 54, 94 are sealed by ring gaskets 107 which are held to tool body 86 by a spring retainer and groove arrangement 108.
  • hanger assembly 50 may be lowered into an underwater well casing, attached to tool 80, then suspended therein by setting the slips 57. Then tool 80 may be removed, withdrawing nipple 88 and seal rings 107, for further operations.
  • FIG. 4A is a vertical section view of the upper portion of connector unit 150 connected to hanger assembly 50.
  • FIG. 4B is a continuation of FIG. 4A showing the lower portion of connector sleeve 160 and hanger assembly 50 from which tubing strings 21 and 22 are suspended.
  • FIGS. 5A and 5B are views similar to FIGS. 4A and 43, except rotated 90.
  • the hanger assembly 50 including lower shoulder 60, setting cone 58, slips 57, mandrel 56, slot 77, the upper end of cement bores 76, alignment dog 51 and tubing run bores 53, 54; can easily be seen.
  • the tubing riser connector body has dual-tubing run bores 156, 158 communicating with hanger bores 53, 54. This connection is sealed by ring seals 153 and 154 affixed to connector body 155 by spring ring and groove arrangements 163, 164.
  • connector sleeve Threadingly connected at the top of connector bore 156, 158 are nipples 166, 168 which extend upwardly to a safety valve package (not shown) above which tubing risers project upwardly for extension to a submerged platform such as 2 in FIG. 1.
  • Connector sleeve surrounds the lower end of connector body 155 and the upper end of hanger assembly 50.
  • the lower portion of connector sleeve 160 is a double-helix alignment surface 170 which converges in a vertical slot 171. The purpose of the double-helix 170 and slot 171 is to automatically align the connector 150.
  • FIGS. 5A and 5B the details of the latching apparatus of connector 150 will be described.
  • the pockets 72 and hub shoulder 73 of hanger body 55 previously described are used for attaching to connector 150 in a similar manner as to the running tool 80 in FIG. 3A.
  • Oppositely opposed latches 182 are retained in connector body recesses 185 by latch foot portions 184.
  • Wedge pieces 191 hold the lips 183 of latches 182 in engagement with hub shoulder 73.
  • the cooperating surfaces 193 between latches 182 and wedge pieces 191 are self-locking tapers.
  • pistons 200 Mounted in connector body 155 for longitudinal movement by pressure are two pistons 200 which have rod portions 202 and heads 204.
  • the rods 202 are connected to wedge pieces 191 by threaded connections 199 and move simultaneously with them and sleeve 160 which is tied to wedge pieces 191 by keys 198.
  • the piston heads 204 are mounted in piston cylinders 206 for movement from a disengaged position at the upper end of the cylinders 206 to the engaged position shown.
  • the upper ends of the cylinders 206 are closed by cylinder plugs 208, 209.
  • Connected to the upper end of each cylinder plug 208, 209 are external conduits 218, 219 the purpose of which will be better understood subsequently hereto.
  • Internal ports 210, 211 and 212 connect the rod side of pistons 204 with conduit 218.
  • Internal ports 214, 215, 216 and 217 connect the head side of pistons 204 with conduit 219.
  • Each cylinder plug 208, 209 is provided with annular seals 228, 229 which seal and isolate the various ports and areas of pressure.
  • Piston heads 204 and piston rods 202 are also provided with annular seals 224 and 222, respectively.
  • FIGS. 611 a step by step explanation of the operation and procedure for utilizing the previously described apparatus will be given.
  • the same reference numbers used in FIGS. 2-5B will be given to corresponding parts in FIGS. 6-11.
  • drilling and setting of casing is performed from a floating drilling vessel and the wellhead equipment is to be located at a submerged platform 2.
  • the 16 inch surface casing would be installed inside of the 30 inch conductor casing 15.
  • the l-'% inch innermost casing would be installed and suspended in the 16 inch casing.
  • tubing would be run in the innennost casing represented in FIG. 6 by the reference number 18.
  • the dualtubing strings 21, 22 are lowered into casing 18 attached to the tubing hanger assembly 50 which is in turn attached to the running tool 80 as previously described with reference to FIG. 3A.
  • the hanger 50 and running tool 80 are lowered on running or handling strings 123 and 124 with slips 57 in the retracted position, until the tubing strings 21, 22 reach their total depth.
  • the strings 21, 22 are of such a length that hanger 50 will then be at a point in casing 18 approximately 100 feet or more below the floor of the body of water in which the well platform is submerged.
  • slips 57 are set by applying pressure to setting cone 58 through handling string 123, internal port 87, nipple 88 and internal port 52.
  • shearpins 65 are sheared releasing the setting cone for upward movement.
  • coaction of stationary mandrel 56 and the moving setting cone 58 causes slips 57 to move outwardly into engagement with the walls of casing 18 as shown in FIG. 7.
  • FIG. 7 also shows an alternative suspension arrangement whereby casing 18 is provided with a support head 130 and the lower end of hanger assembly 50 is provided with a springloaded latch assembly 132 which automatically engages latch grooves in the head 130 for primary support of hanger 50 and the tubing strings 21, 22.
  • the slip means could be used as secondary suspension in the event the tubing strings 21, 22 become stuck before the latch assembly 132 reaches head 130.
  • FIG. 3B shows the cement return bore 76 and slot 77 for allowing cement returns through the hanger assembly 50.
  • the cementing step could be performed before the setting of hanger assembly 50. This would allow reciprocation of the tubing strings during cementing, as some operators prefer.
  • running tool 80 would be disconnected from hanger assembly 50 and removed from the well. This is accomplished by rotating couplings 123 and 124 to the right causing retainer plate 96 and sleeve 90 to move upwardly.
  • the wedge blocks 91 attached to sleeve 90 catch the heel of latch foot portion 84 causing latch lip 83 to pivot out of engagement with hub shoulder 73.
  • nipple 88, guide pin 135 and ring seals 107 are withdrawn also.
  • tubing riser connector 150 safety valve package 250 and tubing risers 300, 301.
  • the safety valve package 250 is installed in the riser strings above nipples 166, 168 which are shown in FIG. 4A.
  • Control lines (not shown) would be run in with the risers 300, 301 for remotely operating the valves 251 and 252.
  • ported nipples 303, 305 Connected in riser string 300 are ported nipples 303, 305 and a landing nipple 304 such as Otis type S.
  • External conduit 218 is connected to ported nipple 30S and external conduit 219 is connected to ported nipple 303.
  • External conduits 218, 219 communicate with piston cylinders 206 through the internal porting 210, 211, 212, 214, 215, 216 and 217 as more fully described heretofore with reference to FIG. A.
  • pistons 200 and sleeve 160 are held in their upper positions so that latches 182 are pivoted away from hanger shoulder 73.
  • connector and hanger 50 are abutting each other connector 150 is latched to hanger 50 by applying pressure through riser 300 with valve 251 closed.
  • pressure is applied below pistons heads 204 through conduit 218 and above piston heads 204 through conduit 219. Since the effective pressure area is the area of piston rods 202, pistons 200 and sleeve are forced downward wedging latches 182 into engagement with hanger shoulder 73 as previously described.
  • the tubing risers 300, 310 pass upwardly through casing 18 to the submerged platform (2 in FIG. 1) where they are connected to a production manifold or Christmas tree" as it is sometimes called.
  • the control lines (not shown) which run from safety valve package 250 to a remote operating station control the opening and closing of valves 251, 252. If for any reason the submerged platform should become damaged to the extent that there is danger of losing well fluid, valves 251, 252 could be closed, shutting the well in at a point well below the mudline. Then, even if the platform turned completely over, the well would be protected.
  • valve 251 If valve 251 is operative, a locator mandrel with tubing plug 280 is run on a wire line through riser 300 and latched in landing nipple 304. Pressure is applied through riser 300.
  • Check valve 281 and seals 282 connect pressure to external conduit 218 routing the pressure below piston heads 204 causing the pistons 200 to move up, releasing the connector latches (182 in FIG. 8).
  • the area of the piston heads 204 less the area of rods 202 is greater than the area of rods 202. Therefore, using the same pressure as was used in setting the latches a greater upward releasing force is applied. The latches should be easily released. Fluid above the piston heads 204 is displaced through external conduit 219 through open valve 251.
  • a releasing adapter or plug 290 is attached to a locating mandrel 291 and run in place on small diameter tubing 292. Pressure is applied through tubing 292. Seals 293 on adapter 290 seal above and below the port in nipple 305, routing the pressure through external conduit 218 below piston heads 204 for releasing the connector 150. Fluid above pistons heads 204 is displaced through external conduit 219, a port 294 in mandrel 291 and adapter internal ports 295 to the annulus between small tubing 292 and riser 300.
  • a method of completing an underwater well having a platform supported from the floor of a body of water and casing means penetrating said floor and projecting upwardly through said body of water to said platform, comprising the steps of: lowering hanger means and at least one-tubing string on a handling string into said casing means to a position where said hanger means will be supported substantially below said floor; cementing said tubing string within said casing means by passing cement through said handling string and said tubing string; disconnecting and removing said handling string; lowering connector means, at least one-tubing riser and valve means into said casing means; and remotely connecting said connector means to said hanger means, placing said tubing string and said tubing riser in fluidtight flow communication, said valve means being installed in said tubing riser at a point substantially below said floor, said tubing riser extending upwardly to said platform.
  • hanger means comprises hydraulically operable slip means in fluid communication with said handling string, the supporting of said hanger means within said casing means being accomplished by applying pressure to said slip means through said handling string forcing said slip means into engagement with said casing means.
  • said latch means comprises piston means within a cylinder, the rod end of said piston means being connected to wedge means, said pressure being applied to both the head end and rod end of said piston means, resulting in an effective force in the direction of said wedge means forcing latch elements into engagement with said hanger means portion.
  • An underwater well comprising:
  • casing means penetrating the floor of said body of water and extending upwardly through said body of water to said platform
  • hanger means supported in said casing means at a point substantially below said floor;
  • At least one-tubing string connected to said hanger means and extending downwardly through said casing means;
  • riser and connector means and valve means being lowerable as a unit separate from said tubing string through said casing for remote engagement with said hanger means
  • said remotely actuatable engageable and disengageable connector means being disposed at the lower end of said riser in engagement with said hanger means placing said tubing string and said tubing riser in fluidtight flow communication through flow bores in said hanger means and said connector means,
  • said remotely operable valve being installed in said riser in such position that when said connector means is in said engagement with said hanger means said valve is located at a point substantially below the floor of said body of water.
  • Apparatus for completing an underwater well having a platform supported at the floor of a body of water and easing means penetrating the floor of said body of water and extending upwardly through said body of water to said platform, said apparatus comprising: hanger means supported in said casing means at a point substantially below said floor; at least onetubing string connected to said hanger means and extending downwardly through said casing means; at least one-tubing riser connected above said hanger means by remotely engageable and disengageable connector means, said tubing riser extending upwardly through said casing means to said platform; and valve means installed in said tubing riser at a point substantially below the floor of said body of water,
  • said hanger means being provided with suspension means around its exterior and connection means whereby a disengageable setting tool may be connected to said hanger and lowered therewith on a handling string to said point of support, said suspension means being in fluid communication with said handling string for hydraulic activation of said suspension means for engaging said casing means to support said hanger means therein.
  • said suspension means comprises slip means, mandrel means fixed relative to said hanger means and setting cone means longitudinally movable on said hanger means, said mandrel means having a frustoconical surface, said setting cone means having a frustoconical surface converging in a direction opposite to said mandrel frustoconical surface, said slip means having oppositely converging frustoconical surfaces on its inner faces and tooth engagement means on its outer faces, said slip means frustoconical surfaces being in contact with said mandrel and setting cone frustoconical surfaces and cooperating therewith on longitudinal movement of said setting cone in response to fluid pressure in said handling string, to wedgingly force said tooth engagement means into engagement with said casing means.
  • connection means comprises shoulder means, said setting tool being provided with latch means and wedge means, said wedge means being longitudinally movable on said setting tool to force said latch means into engagement with said shoulder means providing fluidtight flow communication between said handling string and said tubing string through flow bores in said setting tool and hanger means.
  • said wedge means comprises sleeve means around said setting tool longitudinally fixed to said handling string by retainer means, said handling string being threadingly coupled to said setting tool so that upon make up of said coupling said sleeve is longitudinally displaced to force said latch means into said engagement with said shoulder means.
  • Apparatus for completing an underwater well having a platform supported at the floor of a body of water and easing means penetrating the floor of said body of water and extending upwardly through said body of water to said platform, said apparatus comprising: hanger means supported in said casing means at a point substantially below said floor; at least onetubing string connected to said hanger means and extending downwardly through said casing means; at least one-tubing riser connected above said hanger means by remotely engageable and disenga geable connector means, said tubing riser extending upwardly through said casing means to said platform; and valve means installed in said tubing riser at a point substantially below the floor of said body of water,
  • tubing riser being connected to said hanger means by connector means, said connector means being provided with latch means engageable with shoulder means on said hanger means to provide fluidtight flow communication between said tubing riser and said tubing string through flow bores in said connector means and said hanger means.
  • said orientation means comprises dog means on one of said hanger means and said connector means and sleeve means around the other of said hanger means and said connector means, said sleeve means having a double-helix surface facing toward said dog means as said connector means is lowered to said hanger means, said double-helix surface converging in slot means whereby said double-helix surface first contacts said dog means causing said connector means to rotate until said dog means engages said slot means.
  • said connector means comprises wedge means connected to at least one piston means movable in a cylinder within said connector means, said cylinder being in fluid communication with a remote pressure source whereby fluid pressure may be applied to said piston means causing said wedge means to force said latch means into said engagement with said hanger shoulder means.
  • Apparatus for completing an underwater well comprising hanger means for supporting at least one-tubing string in a casing, said hanger means having a generally cylindrical body through which passes a ilow bore in fluidtight communication with said tubing string, remotely operable suspension means being mounted around said hanger body comprising mandrel means, setting cone means and slip means mounted LII therebetween so that movement of one of said mandrel means and said setting cone means toward the' other forces said slip means into supporting engagement with said casing,
  • suspension means being in fluid communication with a remote pressure source through said handling string and conduit means in said hanger means for remotely operating said suspension means for said supporting engagement with said casing.
  • said latch means comprises wedge means carried by said setting tool operable on the rotation of said handling string to disengage said latches from said hanger shoulder means.
  • Apparatus for completing an underwater well comprising hanger means for supporting at least one-tubing string in a casing, said hanger means having a generally cylindrical body through which passes a flow bore in fluidtight communication with said tubing string, remotely operable suspension means being mounted around said hanger body comprising mandrel means, setting cone means and slip means mounted therebetween so that movement of one of said mandrel means and said setting cone means toward the other forces said slip means into supporting engagement with said casing,
  • connector means in combination with connector means, at least one-tubing riser and valve means lowerable together into said casing for connection to said hanger means, said connector means having remotely operable latch means for engagement with shoulder means on said hanger means to place said tubing riser and said tubing string in fluidtight communication through said hanger flow bore and a flow bore in said connector means.
  • said latch means comprises a hydraulically movable sleeve and a plurality of laterally acting latches activated on the longitudinal movement of said sleeve to engage said hanger shoulder means, said sleeve being provided with first orientation means cooperable with second orientation means on said hanger means to align said tubing riser with said tubing string as said connector means and said tubing riser are lowered toward said hanger means.
  • Apparatus as set forth in claim 29, characterized by piston means within cylinder means carried by said connector, said piston means being connected to said sleeve and movable therewith on introduction of fluid pressure into said cylinder from said remote pressure source to activate said latches.
  • Apparatus for completing a well drilled in the floor of a body of water comprising hanger means for supporting at least one-tubing string within a casing at a point substantially below said water body floor and connector means and at least one-tubing riser lowerable as a unit through said casing for remote engagement with said hanger means, placing said tubing string and said tubing riser in fluidtight flow communication through flow bores in said hanger means and said connector means, said riser projecting upwardly from said connector means to a wellhead at the upper end of said casing for con' nection to a Christmas tree,
  • said connector means being provided with a plurality of latches remotely and laterally movable into engagement with shoulder means on said hanger means to effect said fluidtight flow communication.
  • Apparatus as set forth in claim 32 characterized in that said hydraulic means comprises piston means connected to said sleeve means, said piston means being movable in a cylinder within said connector means, said cylinder being connected through said riser to a remote pressure source for moving said piston means and said sleeve means.
  • Apparatus as set forth in claim 35 characterized in that a remotely operable valve is installed in said riser below said first and second ports at a point substantially below said water body floor.

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US818726A 1969-04-23 1969-04-23 Well completion method and apparatus Expired - Lifetime US3625281A (en)

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Cited By (14)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US4077472A (en) * 1976-07-26 1978-03-07 Otis Engineering Corporation Well flow control system and method
US4126183A (en) * 1976-12-09 1978-11-21 Deep Oil Technology, Inc. Offshore well apparatus with a protected production system
US4143712A (en) * 1972-07-12 1979-03-13 Otis Engineering Corporation Apparatus for treating or completing wells
US4183404A (en) * 1972-07-12 1980-01-15 Otis Engineering Corporation Plural parallel tubing with safety joints or release from suspended receptacle
US4189003A (en) * 1972-07-12 1980-02-19 Otis Engineering Corporation Method of completing wells in which the lower tubing is suspended from a tubing hanger below the wellhead and upper removable tubing extends between the wellhead and tubing hanger
US4236734A (en) * 1978-07-20 1980-12-02 Otis Engineering Corporation Well tubing coupling system
US4320804A (en) * 1979-08-06 1982-03-23 Baker International Corporation Subsea test tree
US4333531A (en) * 1980-02-11 1982-06-08 Armco Inc. Method and apparatus for multiple well completion
US4387767A (en) * 1980-11-13 1983-06-14 Dresser Industries, Inc. Subsurface safety valve system with hydraulic packer
US4637469A (en) * 1984-08-06 1987-01-20 Dresser Industries, Inc. Apparatus and method of well preparation for chemical treatment of produced fluids
US5875849A (en) * 1996-07-26 1999-03-02 Camco Drilling Group Limited Apparatus and method for recompleting wells with coiled tubing
US20030051882A1 (en) * 2001-08-15 2003-03-20 Stewart Hitchon Potable well conversion device
US20050006104A1 (en) * 2001-08-15 2005-01-13 Stewart Hitchon Potable well conversion device
US20080271898A1 (en) * 2007-05-01 2008-11-06 Weatherford/Lamb, Inc. Pressure Isolation Plug for Horizontal Wellbore and Associated Methods

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US4089377A (en) * 1977-01-27 1978-05-16 Societe Nationale Elf Aquitaine (Production) Seal adaptor alignment means and landing tool and method
GB9509547D0 (en) * 1995-05-11 1995-07-05 Expro North Sea Ltd Completion sub-sea test tree
US5813468A (en) * 1996-12-26 1998-09-29 Abb Vetco Gray Inc. Dual casing hanger
CN116146136B (zh) * 2023-04-19 2023-09-08 威飞海洋装备制造有限公司 一种单筒多井井口装置安装方法及单筒多井井口装置

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US3196958A (en) * 1960-04-04 1965-07-27 Richfield Oil Corp Offshore drilling method and apparatus
US3411576A (en) * 1965-07-02 1968-11-19 Otis Eng Co Well tools
US3459261A (en) * 1965-12-13 1969-08-05 Brown Oil Tools Pressure differential expanding means for well packers
US3456723A (en) * 1967-06-30 1969-07-22 Camco Inc Hydraulically set well packer
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Cited By (17)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US4143712A (en) * 1972-07-12 1979-03-13 Otis Engineering Corporation Apparatus for treating or completing wells
US4183404A (en) * 1972-07-12 1980-01-15 Otis Engineering Corporation Plural parallel tubing with safety joints or release from suspended receptacle
US4189003A (en) * 1972-07-12 1980-02-19 Otis Engineering Corporation Method of completing wells in which the lower tubing is suspended from a tubing hanger below the wellhead and upper removable tubing extends between the wellhead and tubing hanger
US4077472A (en) * 1976-07-26 1978-03-07 Otis Engineering Corporation Well flow control system and method
US4126183A (en) * 1976-12-09 1978-11-21 Deep Oil Technology, Inc. Offshore well apparatus with a protected production system
US4236734A (en) * 1978-07-20 1980-12-02 Otis Engineering Corporation Well tubing coupling system
US4320804A (en) * 1979-08-06 1982-03-23 Baker International Corporation Subsea test tree
US4333531A (en) * 1980-02-11 1982-06-08 Armco Inc. Method and apparatus for multiple well completion
US4387767A (en) * 1980-11-13 1983-06-14 Dresser Industries, Inc. Subsurface safety valve system with hydraulic packer
US4637469A (en) * 1984-08-06 1987-01-20 Dresser Industries, Inc. Apparatus and method of well preparation for chemical treatment of produced fluids
US5875849A (en) * 1996-07-26 1999-03-02 Camco Drilling Group Limited Apparatus and method for recompleting wells with coiled tubing
US20030051882A1 (en) * 2001-08-15 2003-03-20 Stewart Hitchon Potable well conversion device
US6817420B2 (en) * 2001-08-15 2004-11-16 Stewart Hitchon Potable well conversion device
US20050006104A1 (en) * 2001-08-15 2005-01-13 Stewart Hitchon Potable well conversion device
US7237614B2 (en) 2001-08-15 2007-07-03 Stewart Hitchon Potable well conversion device
US20080271898A1 (en) * 2007-05-01 2008-11-06 Weatherford/Lamb, Inc. Pressure Isolation Plug for Horizontal Wellbore and Associated Methods
US7690436B2 (en) * 2007-05-01 2010-04-06 Weatherford/Lamb Inc. Pressure isolation plug for horizontal wellbore and associated methods

Also Published As

Publication number Publication date
GB1301491A (enrdf_load_stackoverflow) 1972-12-29
GB1305357A (enrdf_load_stackoverflow) 1973-01-31
FR2039392B1 (enrdf_load_stackoverflow) 1974-05-24
FR2039392A1 (enrdf_load_stackoverflow) 1971-01-15

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