US3313345A - Method and apparatus for offshore drilling and well completion - Google Patents

Method and apparatus for offshore drilling and well completion Download PDF

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US3313345A
US3313345A US372061A US37206164A US3313345A US 3313345 A US3313345 A US 3313345A US 372061 A US372061 A US 372061A US 37206164 A US37206164 A US 37206164A US 3313345 A US3313345 A US 3313345A
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riser
vessel
drilling
relative
force
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Fischer William
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Chevron USA Inc
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Chevron Research and Technology Co
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Priority to US372061A priority Critical patent/US3313345A/en
Priority to NO158287A priority patent/NO122006B/no
Priority to GB23181/65A priority patent/GB1071014A/en
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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
    • E21B17/00—Drilling rods or pipes; Flexible drill strings; Kellies; Drill collars; Sucker rods; Cables; Casings; Tubings
    • E21B17/01—Risers
    • 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
    • E21B7/00—Special methods or apparatus for drilling
    • E21B7/12—Underwater drilling
    • E21B7/128—Underwater drilling from floating support with independent underwater anchored guide base

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  • This invention relates to drilling in earth formations located beneath a body of water, particularly deep, open water such as an ocean. More specically, this invention relates to an apparatus for use in offshore drilling and well completion to prevent bending and buckling of an elongated tubular member which extends from the ocean floor to a drilling platform at the ocean surface.
  • the lower end of the riser is connected to a wellhead, which includes blowout preventers and control equipment, while the upper end of the riser is connected to the drilling vessel.
  • the wellhead is designed to remain stationary on the ocean floor.
  • the drilling vessel on the other hand, is continuously moving under the action of tides, currents, waves and wind. Movement of the vessel is somewhat restricted by anchoring and by special positioning systems. But, the violent and constantly changing forces acting on the vessel often shift it from its position over the well bore by lateral distances in excess of four percent of the water depth. Vertical heaving movements due to Wave action can be expected in addition to the relatively slower vertical movement effected by tides. These heaving movements maybe very substantial.
  • One accepted method of allowing for the relative lateral and vertical movement between the vessel and the wellhead is to place laterally flexible joints and telescopic joints in the riser. This permits the riser to accommodate the movement of the vessel within design limits.
  • the apparatus of this invention is capable of applying tensile forces of large magnitude to the riser in a manner such that the amount of tension applied remains constant regardless of movement of the vessel relative to the wellhead.
  • the large upward force is applied to the riser by the apparatus of this invention in a manner such that the upward force will be dissipated in the event of structural failure of the riser. Thus the riser will not shoot from the water endangering the safety of nearby personnel.
  • the apparatus of this invention also provides for adjustment of the magnitude of the tension applied to the riser by personnel on the drilling vessel as operating conditions an-d the magnitude of tension required vary.
  • the apparatus of this invention includes a piston and cylinder arrangement interposed in the riser to apply longitudinal force to the riser and at the same time to serve as a telescopic joint to permit relative motion between the drilling vessel and the ocean floor, which are connected together by the riser.
  • the riser extends from a connection to the wellhead at the lower end of the riser up to a point near the water surface.
  • a piston is formed at the upper end of this portion of the riser.
  • a second portion of the riser is connected at its upper end to the drilling vessel, and extends downward beneath the water surface.
  • the lower en-d of the second portion of the riser forms a cylinder which surrounds the piston formed at the upper end of the first portion.
  • High pressure tiuid is applied to the cylinder below the piston from a source on the drilling vessel.
  • the high pressure fluid exerts an upward force on the piston, and thereby on the upperend of the rst portion of the riser. This upward force is counter-balanced by a downward force applied to the lower end of the riser either by the wellhead equipment or yby a large mass connected to the lower end of the riser.
  • the liuid pressure source maintains the uid pressure at a substantially constant magnitude regardless of the position -of the piston relative to the cylinder, an-d therefore the amount of tension applied to the riser is substantially independent of vessel movement.
  • the tiuid pressure is adjustable so that the amount of tension applied may be varied as required.
  • This invention also includes novel means for supporting the upper end of the riser from the vessel.
  • the support means is designed to permit free pivotal movement of the vessel relative to the riser as the vessel pitches and rolls.
  • the support includes a gimbal with two horizontal pivotal axes at right angles to each other.
  • the support includes a spherical ball which seats in -a spherical bearing socket.
  • FIGURE 1 is an overall elevation view of the apparatus of this invention in operating position.
  • FIGURE 2 is an enlarged view of portions of FIG- URE l.
  • FIGURE 2a is an alternative arrangement for the lower end of the riser.
  • FIGURE 3 is a schematic diagram of the effect of axial compression on a beam section.
  • FIGURE 4 is a schematic illustration of the elfect of axial compression on a confined fluid.
  • FIGURE 5 is an elevation view, partly in section, of the tensioner and of the gimbal support for the upper end of the riser.
  • FIGURE 6 is a plan view of the gimbal support of FIGURE 5.
  • FIGURE 7 is a sectional view along lines 7-7 of FIG- URE 6.
  • FIGURE 8 is an elevational view similar to FIGURE 5 illustrating a modification of the tensioner and of the top support.
  • vessel 1 is oating on a body of water 2 such as an ocean.
  • the Vessel includes a vertical opening 3 through its hull near the longitudinal and transverse center of the vessel.
  • Supported on the upper deck 4 of the vessel and approximately centered over the opening 3 is a derrick structure 5 from which the upper end of drill pipe 8 is supported by a traveling block 9 and swivel 10.
  • the derrick structure and much of the associated equipment are of a type commonly used in offshore rotary drilling and are not shown in detail.
  • the drill pipe 8 passes vertically through aligned openings in the platform and rotary table and is rotated by the rotary table 7 in a standard manner.
  • Anchors connected to anchor chains 12 and 13 limit the movement of the vessel from its normal position over the well.
  • a wellhead 20 is located on the submerged formation 11 in which the hole is being drilled.
  • the wellhead includes a base 21, and stacked blowout preventers 22 and 23 which are releasably connected to the base by coupling 24.
  • Several lengths of well casing 27 and 28 extend beneath the wellhead into the well.
  • At least two guideposts and 26 extend vertically from spaced points near the circumference of base 21.
  • Guide lines 29 and 30 extending from guideposts 25 and 26, respectively, to the vessel 1 are used to guide equipment as it is lowered from the vessel to the wellhead. These guide lines extend upward through the opening 3 in the bottom of the vessel, over pulleys 31 and 32, and are connected at their upper ends to tensioning devices such as constant tension Winches 33 and 34 respectively.
  • the riser may ⁇ be lowered to connect the floating vessel to the wellhead.
  • This riser is releasably connected at its lower end to the wellhead by coupling and is connected at its upper end to the vessel in a manner which will be described below.
  • the riser includes a ball and socket joint 48 near its lower end to reduce the torsional stress transmitted to the wellhead as the vessel shifts laterally from its position over the well under the action of wind, tides, waves, and currents.
  • the heavy coupler 45 is pendant below the universal ball joint 48. Guide arms 46 and 47 are aligned on the center of 48 so that the connection at coupler 45 is assured and is independent of the angularity of the riser.
  • the guide arms 3S and 36 may be omitted.
  • the major portion of the riser consists of a series of elongated tubular members 51 connected end to end by couplings 52 to extend from telescopic joint 50 to ball and socket joint 48.
  • High density drilling fluid is fed to the well from a pump on the vessel.
  • the drilling uid passes through iiexible hose 55, down through a passageway in the axis of the drill pipe, and out bit 56 at the bottom of the well.
  • the drilling uid is returned to the sump by passing upwardly around the -outside of the drill pipe through well casings 28 and 27, through wellhead and then upward through the riser.
  • the drilling fluid is returned to the mud system on the vessel through pipe 57 which is ilexibly connected to the riser near its upper end.
  • x distance along the axis of the beam in inches from the nearest support
  • y lateral deection of the beam in inches
  • A6 small angle along arc of slightly curved beam in radians
  • q lateral force per unit of beam length in pounds per inch
  • F axial compressive force in pounds
  • R radius of curvature ofthe bent beam in inches.
  • Timoshenko Strength of Materials, 2nd ed., vol. 1, p. 135 (1940).
  • the fundamental detiection equation is Eldyq as is also shown in Timoshenko, supra, at p. 137.
  • 80 is the undeected position of the axis of beam portion 81.
  • the axis has been deected to position 82 under the axial compressive forces F.
  • this derivation made no assumption that the beam was solid, and if the beam is a tubular pipe the derivation applies equally well whether the axial force is in the internal fluid or in the pipe wall. Thus it may be concluded that it is the algebraic sum of the axial forces applied to the internal uid and to the pipe wall that must be considered in calculating the pipe deflection. Thus buckling can occur with a high uid pressure even though the axial force in the pipe wall is tensile if the compressive force in the fluid exceeds the tensile force in the pipe wall so that the net axial force is compressive.
  • FIGURE 4 there is shown a longitudinal crosssection through a length of tubular steel pipe 'lled with a liquid 61.
  • the pipe is extremely long in comparison with its diameter so that it acts as a long column with a large slenderness ratio. Portions of its length have been omitted for convenience in the drawings.
  • the ends of the pipe 60 are sealed by slidable pistons 62 and 63 which are free to move axially along the pipe 69.
  • Each piston includes a pivot bearing 64 on its outer face.
  • a clamp 65 including a screw member 66 is designed to exert pressure between stationary face 67 of the clamp and movable face 68 of the screw.
  • the pressure is transmitted through the pistons 62 and 63 to the fluid 61, which is substantially incompressible.
  • a sutliciently great force placed on bearing 64 by tightening of the screw 66 will cause the pipe 60 to buckle from its original straight position.
  • the deflection of the pipe is indicated by the letter a. It is apparent that as the slenderness ratio of the pipe 60 becomes greater, less force is required to buckle the pipe since it acts as a long column.
  • compressive force applied to a liquid confined in an elongated tubular member causes ilexing and buckling of the tubular member in t-he same manner as compressive forces applied to a solid long column.
  • Equation 3 can be obtained by integrating the lateral component of fluid pressure over the length Ax of the column. Since the radially outward arc length is greater than the radially inward arc length in FIGURE 3, the net force would be radially outward. Similarly iluid pressure outside of the pipe will produce a net radially inward force.
  • Equation 7 A11-internal cross-sectional area of pipe in square inches
  • A2 external cross-sectional area of pipe in square inches
  • P1 internal iluid pressure in pounds per square inch
  • the pressure of the drilling uid will be equal to some substantially constant value at the top of the riser due to pump pressure and friction in the return pipe 57, and will increase linearly with depth to a maximum at the bottom of the well bore.
  • the average compressive stress S across any transverse section of the riser wall will include the net stress in the riser from all sources such as vessel movement, equipment bearing on the riser, and the weight of the riser itself. From these quantities the net axial compressive force F acting on any section through the riser may be calculated by use of Equation 7.
  • the riser While in the absence of lateral environmental forces, the riser could theoretically withstand some axial compressive force over relatively short increments of its length, for practical purposes1 and to insure safe operation, it is preferred to assume that the net axial compressive force F in Equation 7 must equal zero or preferably be negative, i.e., tensile rather than compressive, throughout the length of the riser, and then to add an overpull, or additional tensile force, to limit the deflection from the environmental forces.
  • Equation 7 For convenience it may be preferable to express Equation 7 as it applies to risers in oflshore drilling as: the net axial compressive force acting on any transverse crosssection is equal to the weight in water of the column of drilling fluid above that section, plus the weight in Water of the riser column above that section, plus any other axial compressive forces applied directly to the riser above that section.
  • This relationship is based on the assumption that the pressure of the drilling fluid is zero at the top of the column and that its pressure increases linearly with depth in proportion to its weight. While not precisely t-rue in all cases this form of the equation is generally adequate to arrive at a practical determination of the forces involved in a riser used for offshore drilling.
  • A4 external cross-sectional area of the well casing or drill pipe in square inches.
  • P3 pressure of fluid in space between interior wall of riser and exterior wall of well casing or drill pipe in pounds per square inch.
  • P4 pressure of fluid inside of well casing or drill pipe in pounds per square inch.
  • S2 average compressive stress in the well casing or drill pipe in pounds per square inch.
  • Equation 7 the net axial compressive force tending to bend or buckle the riser at any transverse cross section is equal to the algebraic sum of all the axial forces acting on the walls of the riser at that section and all the axial forces acting on all materials within the riser at that section minus the product of pressure of the sea water outside that section times the external area of the riser.
  • the axial component of the vertical force F is substantially equal to the vertical force F and may be assumed to be the same.
  • the maximum force F from Equation 7 will occur at the lower end of the riser. It will be approximately equal to the weight in water of the entire riser column (27,100 pounds), plus the weight in water of the entire volume of drilling fluid contained in the riser (29,200 pounds), giving a total F of 56,300 pounds. Thus an upward force in excess of this amount is required.
  • the angle of the riser at the ball joint can be limited to live degrees by an overpull of 20,300 pounds (Equation 9).
  • This overpull is an upward force in addition to the 56,300 pounds required to reduce F to zero. Further overpull can be added as a safety factor and/or to account for friction in the telescopic joint.
  • a counteracting downward force is necessary to prevent the riser from lbeing pulled out of the water.
  • the weight in water of the riser opposes the upward force but is insuflicient to completely counteract it.
  • the wellhead and associated equipment may be relied on to either completely or partially counteract the upward force, either by its weight, or by weights added to the wellhead, or by anchoring the wellhead or the well casing which is suspended from it to the submerged formation.
  • Another manner of providing part or all of the downward force is by connecting a large weighted mass or counterweight to the bottom end of the riser.
  • the apparatus of this invention uses fluid pressure to provide the upward force.
  • the preferred embodiment of this invention applies the uid pressure to a piston and cylinder combination which is incorporated in the riser and forms a part of it.
  • the piston and cylinder arrangement also serves as a telescopic joint to permit elongation and contraction of the riser as the vessel moves relative to the ocean bottom.
  • the combination telescopic joint and tensioner designated generally as 50 in FIGURES l and 2, will be described with particular reference to FIGURE 5.
  • the upper portion of the riser includes a tubular pitcher nipple 101 which is connected to the vessel below rotary table 7 in a manner which will be described later.
  • a flange 103 is rigidly connected at the lower end of pitcher nipple 101 ⁇ and is braced thereto by members 104.
  • Tubular member 105 extends below pitcher nipple 101 and is aligned therewith to form a continuous conduit.
  • Flange 106 at the upper end of tubular member 105 is connected to ange 103 in any suitable manner such as by bolts 102.
  • the uppermost one of the tubular conductor members 51 is designated 51a. It includes an enlarged diameter portion 107 at its upper end above transition 115. This enlarged diameter portion 107 receives tubular member 105 in telescopic relationship. Since tubular member 105 will move with the vessel while enlarged diameter portion 107 is axially fixed relative to the ocean bottom, the overlap between members 105 and 107 is such that they will form a continuous conduit at all positions of the vessel relative to the wellhead within selected design limits.
  • Cylinder 108 surrounds tubular member 105 and the overlapped portion of 107. It is connected at its upper end to flange 106. Flange 106 thus serves as a cap to seal fil the upper end of the space between tubular member and cylinder 108. The lower end of cylinder 108 is sealed by cap 119. Rings and 121 provide a sliding seal between enlarged diameter portion 107 of upper conductor member 51a and cap 119. An annular piston 116 is connected to the upper end of enlarged diameter portion 107 and surrounds tubular member 105 in axially sliding rela tionship. Rings 117 and 118 provide a sliding seal between piston 116 and cylinder 108.
  • High pressure uid is supplied to cylinder 108 near its lower end through conduit 123 from a source on the drilling vessel.
  • This high pressure iluid acts on the lower face of piston 116 to apply an upward force to the upper end of the lower portion of the riser.
  • the magnitude of the upward force applied to the riser may be varied by adjusting the pressure of the uid supplied by the source. Such adjustment may be made by any known device, and the adjusting means will not be described in detail herein.
  • cylinder 16S and tubular member 105 will move axially relative to annular piston I116.
  • the pressure of the fluid supplied to the cylinder through conduit 123 is regulated so that the pressure remains nearly constant in spite of such relative movement, and therefore the upward force on the upper end of the riser remains relatively constant.
  • the regulation may be by any of several well-known devices.
  • perforations 122 in tubular member 165 serve as vents. These perforations permit the drilling fluid conveyed through the riser to pass through the perforations into the portion of the cylinder above piston 116 as the piston moves downwardly relative to the cylinder; and permit the drilling uid to pass out of this space as the piston moves upward relative to cylinder 108.
  • the perforations 122 are preferably sufficiently large to permit cuttings which may be suspended in the drilling fluid to flow readily out of the space above piston 116 rather than to accumulate therein.
  • Stops 125 and 126 attached to the outer surface of enlarged diameter portion 107 limit downward movement of piston 116 relative to cylinder 108, while stops 135 and 136 attached to cylinder 10S limit upward movement.
  • piston 116 will rise under the inuence of the high pressure uid until the piston reaches the upper limit of its stroke. At that point the relative movement between the upper and lower portions of the riser will be stopped and the riser will remain suspended from the drilling vessel.
  • the upward force exerted on piston 116 by the high pressure fluid will be transmitted to cylinder 108 where it will be opposed by the equal and opposite downward force exerted on cap 119 by the Huid.
  • the upward force is counteracted immediately on failure of the riser, and no hazard is created.
  • the opposing downward pull at the lower end of the riser may be provided by the wellhead and associated equipment itself, as shown in FIGURE 2.
  • a concentrated counterweight 155 may be suspended from the riser by rigid gusset plates 156 and 157 as shown in FIGURE 2a.
  • the count/erweight is suspended around ball joint 4S so that the center of gravity of the counterweight is no higher than the center of rotation of the ball joint.
  • counterweight 155 exerts no adverse moment about ball joint 48.
  • FIGURE 8 A modified form of the tensioner of this invention is illustrated in FIGURE 8.
  • tubular member 105 is not perforated.
  • the cylinder 108 includes .an outlet near its upper end which vents the upper portion of the cylinder to the atmosphere.
  • Rings 131 and 132 in piston 116 provide a sliding seal between the interior space of the piston and the exterior surface of l. 1 tubular member 105.
  • a seal can be provided between tublar members 105 and enlarged diameter portion 107 of uppermost conductor member 51a, at the lower end of tubular member 105.
  • an oil bath 134 in the lower end of the cylinder to lubricate the contact between portion 107 and rings 120 and 121.
  • Rotary table 7 is supported on skid beams 138, which lare supported on the main support platform 6.
  • Support platform 6 includes main longitudinal beams 141 and short transverse beams 142 and 143 extending between adjacent longitudinal beams 141 beneath the rotary table. Beams 142 and 143 are strengthened by plates 144 and 145 respectively.
  • the upper end of the riser be supported from the above described structure at a position closely adjacent to the rotary table so that the bore of the pitcher nipple 101 will not pass from beneath the bore of the rotary table 7 as the vessel 1 pitches and rolls relative to the upper end of the riser.
  • Pitcher nipple 101 includes a special collar 139 at its upper end.
  • the internal surface of collar 139 is funneled, as is shown at 140, to aid in passing drill string and other materials into the upper end of the riser, particularly when the rotary platform is at an angle to the horizontal because of pitching and rolling of the vessel.
  • the upper end of the riser is supported from platform 6 by a gimbal with two mutually perpendicular pivotal axes to permit universal angular movement of the vessel relative to the upper end of the riser.
  • One pivotal axis of the gimbal comprises a pair of hollow spindles 158, each of which is mounted for rotation relative to the riser in one of a pair of lbearings 157. Each bearing is enclosed in one of a pair of housings 150 which are attached to special collar 139 to extend downward on diametrically opposed sides of pitcher nipple 101.
  • the axis of spindles 158 intersects the axis of the riser at a right angle.
  • An elongated plate 154 is attached to each spindle 158 adjacent to the outer face of the associated housing 150. Each plate 154 rotates with its associated spindle in a plane parallel to the riser axis. An elongated plate 155 is attached to each spindle 158 for rotation therewith adjacent to the inner face of the associated housing 150. A retaining bolt 156 serves to connect each spindle 158 to its associated plates 154 and 155. Each of the plates 154 is also connected to its associated plate 155 by small transverse plates 159 and 160. Thus plates 154 and 155 are mounted for pivotal movement about an axis at right angles to the longitudinal axis of conductor member 101 in a plane parallel to main beams 141.
  • a housing 166 enclosing a bearing 165 extends upwardly between each pair of plates 161 and 162.
  • Each pair of plates 161 and 162 is pivotally connected to its associated housing through spindle retaining bolt 168, hollow spindle 169 and bearing 165.
  • Each housing 166 is fixed relative to the vessel through plate 175, which rests on supports 180 which, in turn, are connected to the flanges of beams 141.
  • Members 176, 177, 178 and plates 181 rigidify the structure.
  • Plate 175 includes an opening 179 through which tubular member 101 extends.
  • the axes of spindles 169 are in longitudinal alignment with each other and are perpendicular to the axes of spindles 158.
  • the gimbal structure supports the upper end of the riser while permitting the vessel to move angularly relative thereto about two mutually transverse axes.
  • Both axes preferably lie in a common plane so that yboth may be placed at the highest possible position relative to the upper end of the riser, thereby reducing the lateral misalignment of the upper end of the riser relative to the central passage through the rotary table, as the vessel pitches and rolls.
  • Bearings are preferably thrust bearings since the pull of the riser will at times have a component along the axis of bolts 168, or thrust bearings may be installed between 161 and beams 142 and 143. Bearings 157 may also be thrust bearings although there is little likelihood of their receiving anything but right angle loads.
  • the special collar 139 of the riser is chamfered at 183 so it will not strike the upper anges of beams 141.
  • FIGURE 8 An alternative arrangement for connecting the upper end of the riser to the floating vesesl is shown in FIGURE 8.
  • spaced transverse beams 250 extend between adjacent longitudinal beams of support platform 6.
  • Horizontal plate 251 extends radially inward from the beams 250 and 141.
  • the plate 251 terminates in a spherical bearing surface 252.
  • Plate 2511 is rigidly connected to and braced from the structural beams by plates such as 249.
  • a spherical ball 253 Seated in rotatably sliding relationship on bearing surface 252 is a spherical ball 253.
  • Tubular member 101 is connected to ball 253 'and suitably braced by plates 256.
  • Ball 253 and bearing 252 serve to sup-port the riser while, at the same time, permitting the vessel to move angularly relative to the riser in a manner similar to the gimbal of FIGURES 5 to 7.
  • an elongated tubular conduit including an elongated lower tubular member and an elongated upper tubular member connected to said lower member in axially aligned telescopic relationship, means for fixing t-he lower end of said lower member against axial movement relative to the ocean bottom, me'ans for attaching the upper end of said upper member to a platform for axial movement therewith relative to said lower member, and adjustably variable fluid pressure means on said platform operatively connected to exert a regulated substantially constant upward preselected axial force on the upper portion of said lower member as said upper member moves axially relative to said lower member within selected design limits.
  • An elongated tubular conduit for connecting a floating vessel to a subaqueous formation comprising an elongated lower tubular member, means for xing the lower end of said lower member relative to and 4adjacent said subaqueous formation, an elongated upper tubular member telescopically connected to said lower tubular member, means for attaching the upper end of said upper member to said vessel for random movement relative to said subaqueous formation under the inuence of water and wind forces, a piston and cylinder operatively connected to exert an upward axial preselected force on the upper portion of said lower member, said piston and cylinder being proportioned to permit said upper member to move axially relative to said lower member as said vessel moves relative to said subaqueous formation within selected design limits, and adjustably variable means for supplying fluid under a regulated substantially constant preselected pressure to said cylinder for maintaining said upward axial force substantially constant at a predetermined magnitude as said vessel moves relative to said subaqueous formation.
  • a tensioning device for an oTshore riser which riser comprises a pair of telescopic-ally connected elongated tubular members for connecting a floating vessel to a subaqueous well as said vessel moves randomly relative to said well, said tensioning device comprising: a rst annular surface attached to the telescoped end of one of said tubular members for movement therewith, a second annular surface attached to the other of said tubular members for movement therewith, said rst and second annular surfaces Iforming the ends of a sealed chamber which extends as said riser elongates and contracts as said riser retracts, and adjustably variable means for supplying fluid under a regulated substantially constant preselected pressure to said chamber for applying substantially constant preselected axial force to said members as said Vessel moves relative to said subaqueous Well.
  • an elongated tubular conduit for connecting a floating vessel to a well bore to pass dense drilling uid and drilling tools between said vessel and said well bore, comprising: an elongated lower tubular member and an elongated upper tubular member, means for attaching the lower end of said lower member to said well bore, means for attaching the upper end of said upper member to said oating vessel, the upper end of said lower member and the lower end of said upper member being axially aligned and overlapping in telescopic relationship at all positions of said vessel relative to said well bore within selected design limits, an annular piston attached around one of said telescoped ends, a cylinder surrounding said piston in axial slideable relationship and attached to the other of said telescoped ends, said cylinder being of suflicient length to permit axial extension and retraction of said conduit suilicient to accommodate vessel movement relative to said Well bore within said design limits, adjustably variable means for supplying a pressure uid under a regulated substantially constant preselected pressure to said cylinder
  • a riser attached at its lower end to a stationary wellhead below the ocean surface and at its upper end to a oating vessel, means in the lower portion of said riser permitting angular movement of said riser as said vessel moves laterally relative to said wellhead, and means in said riser near its upper end for permitting axial extension and retr-action of said riser and for maintaining a constant tension in said riser, substantially continuously during said offshore drilling
  • said last recited means comprising a telescopic connection in said riser, an annular piston connected around one member of said telescopic connection, a cylinder surrounding said piston in axially slideable relationship and connected to the other member of said telescopic connection, said piston yand cylinder permitting extension and retraction of said riser suicient to compensate for a vessel movement relative to said wellhead within selected design limits, adjustably variable means for supplying fluid under a regulated substantially constant preselected pressure to said cylinder for application of a preselected substantially constant upward
  • a gimbal for connecting the upper end of a riser to a oating drilling vessel adjacent the underside of a rotary table on said Vessel, said gimbal comprising: a tirst pair of plates connected to the riser near its upper end for rotation in a pair of parallel planes on diametrically opposed sides of said riser about a rst axis which intersects the longitudinal axis of the upper end of said riser at a right angle, a second pair of plates attached -between said tirst pair of plates to form a rectangle around the upper end of said riser, and means connecting said second pair of plates to said vessel for rotation about a second axis which intersects said rst axis at a right angle at the point of intersection of said lirst axis with the longitudinal axis of said riser.

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US372061A 1964-06-02 1964-06-02 Method and apparatus for offshore drilling and well completion Expired - Lifetime US3313345A (en)

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US372061A US3313345A (en) 1964-06-02 1964-06-02 Method and apparatus for offshore drilling and well completion
NO158287A NO122006B (enrdf_load_stackoverflow) 1964-06-02 1965-05-31
GB23181/65A GB1071014A (en) 1964-06-02 1965-05-31 Apparatus for offshore drilling and well completion

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US4311327A (en) * 1979-12-20 1982-01-19 Exxon Production Research Company Universal joint for multiple flowline system
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NO122006B (enrdf_load_stackoverflow) 1971-05-10

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