EP1923535A1 - Clapet de fond de puits non-retour muni d'un disque de rupture - Google Patents

Clapet de fond de puits non-retour muni d'un disque de rupture Download PDF

Info

Publication number
EP1923535A1
EP1923535A1 EP06124022A EP06124022A EP1923535A1 EP 1923535 A1 EP1923535 A1 EP 1923535A1 EP 06124022 A EP06124022 A EP 06124022A EP 06124022 A EP06124022 A EP 06124022A EP 1923535 A1 EP1923535 A1 EP 1923535A1
Authority
EP
European Patent Office
Prior art keywords
tubing string
tool
string
valve system
passage
Prior art date
Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
Withdrawn
Application number
EP06124022A
Other languages
German (de)
English (en)
Inventor
Jörg Ernst Shell Gabon Eckerlin
Douwe Johannes Runia
Paul Neilson Pioneer Oil Tools Ltd Wood
Current Assignee (The listed assignees may be inaccurate. Google has not performed a legal analysis and makes no representation or warranty as to the accuracy of the list.)
Shell Internationale Research Maatschappij BV
Original Assignee
Shell Internationale Research Maatschappij BV
Priority date (The priority date is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the date listed.)
Filing date
Publication date
Application filed by Shell Internationale Research Maatschappij BV filed Critical Shell Internationale Research Maatschappij BV
Priority to EP06124022A priority Critical patent/EP1923535A1/fr
Publication of EP1923535A1 publication Critical patent/EP1923535A1/fr
Withdrawn legal-status Critical Current

Links

Images

Classifications

    • E—FIXED CONSTRUCTIONS
    • E21—EARTH DRILLING; MINING
    • E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B34/00—Valve arrangements for boreholes or wells
    • E21B34/06—Valve arrangements for boreholes or wells in wells
    • E21B34/063—Valve or closure with destructible element, e.g. frangible disc
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH DRILLING; MINING
    • E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B10/00—Drill bits
    • E21B10/08—Roller bits
    • E21B10/18—Roller bits characterised by conduits or nozzles for drilling fluids
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH DRILLING; MINING
    • E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B10/00—Drill bits
    • E21B10/62—Drill bits characterised by parts, e.g. cutting elements, which are detachable or adjustable
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH DRILLING; MINING
    • E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B4/00—Drives for drilling, used in the borehole
    • E21B4/02—Fluid rotary type drives
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH DRILLING; MINING
    • E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B47/00—Survey of boreholes or wells

Definitions

  • the invention relates to a valve system for use in a tubing string.
  • Valve systems are, for example, used in the field of drilling and surveying wellbores formed in Earth formations.
  • U.S. Patent Application Publication No. 2004/0118611 filed by Runia et al. describes methods and apparatus for drilling and surveying a wellbore in subsurface Earth formations in which a set of survey instruments is placed within a pipe or conduit ("tubing string") used to convey a drill bit into the wellbore.
  • the set of survey instruments is able to exit the interior of the tubing string by a special tool causing a center segment of the drill bit to release, thus creating an opening for the survey instruments to leave the tubing string and enter the wellbore below the bottom of the pipe or conduit.
  • tubing string is used in the description which follows because the invention is not limited in scope to use with what is ordinarily understood as a drill string. Such understanding is that a drill string used to drill a borehole includes segments or “joints" of pipe threadedly coupled end to end such that a borehole may be drilled to a selected depth in the Earth. It is within the scope of the present invention to use coiled tubing or similar tube, pipe or conduit to extend a drilling tool assembly into the Earth's subsurface to drill a well.
  • tubing string is intended to include any pipe, tubing or conduit that may be extended into the Earth, whether such conduit is segmented (drill pipe, tubing and the like) or substantially continuous (coiled tubing).
  • a check valve is a one-way valve that enables flow of fluid from the interior of the tubing string to the wellbore, but not the reverse.
  • Embodiments of a check valve known in the art include a sleeve type valve that is movable under fluid pressure inside the tubing string against a biasing device, such as a spring. When move by the fluid pressure, the sleeve exposes ports such that fluid may flow through the lower end of the tubing string. Generally, the interior of the sliding sleeve is closed such that solid objects disposed in the tubing string cannot move freely through the sleeve.
  • a valve system for use in a tubing string extending into a borehole, comprising a valve device arranged to open a passage to fluid flow upon application of a fluid pressure to the valve device, wherein the valve device is provided with an interior space for passage of a tool string therethrough, and a seal member arranged to seal the interior space, the seal member being configured to rupture upon contact with the tool string moved through said interior space.
  • valve device includes a sliding sleeve disposed in an internal bore of the valve system, the sliding sleeve and internal bore being cooperatively arranged to open said passage to fluid flow upon application of said fluid pressure to the sliding sleeve.
  • valve system further comprises a mandrel having couplings for coupling the mandrel to the tubing string, wherein said internal bore is formed in the mandrel.
  • the valve system suitably further comprises a biasing device arranged to move the sliding sleeve to close said passage to fluid flow in the absence of sufficient pressure on an upper end of the sliding sleeve.
  • the seal member is a burst disk configured to rupture upon contact with the tool string moved through said interior space.
  • FIGS. 1 through 5 The description that follows with reference to FIGS. 1 through 5 is related to a method and device shown in U.S. Patent Application Publication No. 2004/0118611 filed by Runia et al. and incorporated herein by reference. Such method and apparatus may be adapted to be used, in some embodiments, with a tool assembly 160 disposed inside a tubing string 12 as set forth herein.
  • the wellbore 1 extends from the Earth's surface into a subsurface Earth formation 2.
  • the wellbore 1 is shown as deviated from vertical, wherein the curvature in the FIG. 1 has been exaggerated for the sake of clarity. It is contemplated that the present invention will have particular advantages for use in such deviated wellbores, however the deviation of the wellbore is not a limit on the scope of the invention.
  • At least the lower part of the wellbore 1 shown in FIG 1 may be formed by the operation of components coupled to the lower end of the tubing string 12.
  • the components coupled to the lower end of the tubing string 12 are collectively referred to as a bottom hole assembly 8, which includes a drill bit 310, a check valve 10 (described in more detail with reference to FIGS. 6 and 7), a drill steering system 312 and a surveying system 315.
  • the bottom hole assembly 8 is provided with a passage 320 forming part of a passageway for the tool assembly 160, which may between a first position 328 in the interior of the tubing string 12, above the bottom hole assembly 8, and a second position 330 inside the wellbore 1 below the tubing string 12, below the bottom hole assembly 8 and below the drill bit 310.
  • the upper part of the tool assembly 160 can remain in the tubing string 12, for example, hung in or even above the bottom hole assembly 8. For purposes of defining the present invention it is sufficient that the lower part of the tool assembly 160 reaches the second position 330 in the wellbore 1. It should be noted that sensors may be included in the tool assembly 160 that can be used to measure one or more parameters in the wellbore as the tool assembly 160 is lowered from the surface to position 328, with measurement data stored to memory or transmitted to the surface.
  • the sensors can also make measurements behind the drill bit 310 in logging while drilling ("LWD") fashion as the well is drilled, in addition to measuring as described below when the tool assembly 160 is in position 330 as the tubing string 12 and bit 310 are withdrawn from the well.
  • LWD logging while drilling
  • the portion of the tubing string 12 adjacent to the tool assembly 160 can be composed of composite or other electrically non-conductive material to facilitate making measurements with sensors adversely affected by the presence of steel or other electrically conductive materials.
  • antenna coils can be located in grooves cut into the outside of the section of the tubing string 12 containing the tool assembly 160, and these coils used to make an induction resistivity measurements of the formations outside the wellbore. Power to the coils and signal received in the coils can be communicated across the tubing wall using electrical feed-through bulkheads of types well known in the art. Such electrically non-conductive material, whether forming an entire segment of the tubing string 12 or whether in the form of "windows" in the tubing string 12, may also provide a path for electromagnetic energy if such is used for telemetry of data from the tool assembly 160 to the Earth's surface, and/or telemetry from the Earth's surface to the tool assembly 160.
  • the terms upper and above are used to refer to a position or orientation relatively closer to the surface end of the tubing string 12, and the terms lower and below for a position relatively closer to the end of the wellbore during operation.
  • the term longitudinal will be used to refer to a direction or orientation substantially along the axis of the tubing string 12.
  • the drill bit 310 is provided with a releasably connected insert 335, which will be discussed in more detail with reference to FIG. 4.
  • the insert 335 forms a selectively removable closure element for the passageway 320, when it is in its closing position, i.e. connected to the drill bit 310 as shown in the FIG. 1.
  • the surveying system 315 of FIG. 1 is shown in more detail.
  • the surveying system of this embodiment can be a measurement/logging while drilling (“MWD/LWD”) system comprising a tubular sub or collar 351 and an elongated probe 355.
  • the upper end of the tubular sub 351 is connectable to the upper part of the tubing string 12 extending to the surface, and the lower end is connectable to the steering system 312.
  • the probe 355 contains surveying instrumentation, a gamma ray instrument 356, an orientation tool 357 including e.g.
  • an magnetometer and accelerometer for determining dip and azimuth of the wellbore, various logging sensors (such as electromagnetic, acoustic, or nuclear sensors), a battery pack 358, and a mud pulser 359 for data communication with the Earth's surface.
  • the collar 351 can also contain surveying instrumentation.
  • An annular shoulder 365 is arranged on the inner circumference of the tubular sub 351, on which the probe can be hung off.
  • the outer surface of the probe is provided with notches 367 on which keys 369 are arranged that co-operate with the annular shoulder 365.
  • the notches 367 allow for fluid to flow through the MWD/LWD system, and also induce the mudflow to go through the pulser section 359.
  • the upper end of the probe 355 is arranged as a connection means 372 such as a fishing neck or a latch connector, which co-operates with a tool such as a wireline tool or a pumping tool that can be lowered from surface and connected to the connection means.
  • the probe can thus be pulled or pumped upwardly so as to remove the probe 355 from the collar 351.
  • the MWD/LWD system has dimensions such that the interior of the collar 351 after removal of the probe 355 represents a passageway 320 of suitable size for passage of at least the lower part of the tool assembly 160.
  • a collar-based MWD/LWD system can be used, wherein all components are arranged around a central longitudinal passageway of required cross-section, and do not include the probe 355.
  • a mud pulser can be provided that comprises a ring-shaped rubber member around the passageway, which can be inflated such that the rubber member extends into the passageway thereby creating a mud pulse.
  • Other types of pulsers include valves that when open divert some of the fluid flow inside the tubing string into the annular space between the wellbore and the tubing string, and thus do not obstruct the central passageway.
  • Still other MWD/LWD systems include no pulser.
  • Such systems may include electromagnetic or acoustic telemetry to communicate data to the Earth's surface, or may merely record data in a suitable storage device in the MWD/LWD system itself, for recovery when the MWD/LWD system is removed to the Earth's surface.
  • FIG. 3 an embodiment of the drill steering system 312 of FIG. 1, in the form of a mud motor 404 in combination with a bent housing 405 will now be explained.
  • the bent housing 405 is shown with an exaggerated bend angle between the upper and lower ends for clarity of the illustration. Ordinarily, the bend angle is on the order of less than three degrees.
  • the bent housing 405 has an interior comparable to ordinary positive displacement or turbine-type drilling motors.
  • the upper end of the mud motor 404 can be directly or indirectly connected to the lower end of the surveying system 315.
  • a mud motor converts hydraulic energy from fluid (drilling mud) pumped from the Earth's surface to rotational energy to drive the drill bit (310 in FIG. 1). Such energy conversion enables bit rotation without the need for tubing string rotation, and thus is suitable for drilling using coiled tubing strings.
  • the mud motor 404 schematically shown in FIG. 3 is a so-called positive displacement motor ("PDM”), which operates on the Moineau principle.
  • PDM positive displacement motor
  • the Moineau principle states that a helically-shaped rotor, shown at 406, with one or more lobes will rotate when it is placed inside a helically shaped stator 408 having one more lobe than the rotor when fluid is moved through annulus between stator and rotor.
  • Rotation of the rotor 406 is transferred to a tubular bit shaft 410, to the lower end 412 of which the drill bit (310 in FIG. 1) can be connected.
  • the lower end of the rotor 406 is connected via connection means 415 to one end of a transfer shaft 418.
  • the transfer shaft 418 extends through the bent housing 405 and is on its other end connected to the bit shaft via connection means 420.
  • the transfer shaft 418 can be a flexible shaft made from a material such as titanium that is able to withstand the bending and torsional stresses.
  • the connection means 415 and 420 can be arranged as universal joints, constant velocity joints or other flexible coupling.
  • the bit shaft 410 is suspended in a bit shaft collar 423, which is connected to or integrated with the stator 408, through bearings 425.
  • a seal 427 is provided between bit shaft 410 and bit shaft collar 423.
  • connection means 420 is arranged to release the connection between the transfer shaft 418 and the bit shaft 410 when upward force is applied to the rotor 406.
  • connection means can be formed as co-operating splines on the lower end of the transfer tool and on the upper part of the bit shaft.
  • a suitable latch mechanism that can be operated by longitudinal pulling/pushing is another option.
  • connection means 430 such as a fishing neck or a latch connector, which co-operates with a tool that can be lowered from surface, connected to the connection means, and pulled or pumped upwardly so as to release the connection at connection means 420.
  • the upper end 432 of the bit shaft 410 is funnel-shaped so as to guide the lower end of the transfer tool 418 to the connection means 420 when the rotor 406 is lowered into the stator 408 again.
  • Fluid passages 435 for drilling fluid can be provided through the wall of the bit shaft 410, to allow circulation of drilling fluid during drilling operation, when the rotor 406 is connected to the bit shaft 410 through connection means 420.
  • a means that locks the bit shaft 410 in the bit shaft collar 423 when the rotor 406 has been disconnected from the bit shaft 410.
  • the minimum inner diameter of the stator 408 and the bit shaft 410 are dimensioned such that a sufficiently large longitudinal passageway for at least the lower part of the tool assembly 160 is provided, forming part of the passageway 320 of FIG. 1.
  • a rotary steerable system generally consists of an outer tubular mandrel having the outer diameter of the tubing string. Through the interior of the mandrel runs a piece of drill pipe of smaller diameter. The drill string or bottom hole assembly above the rotary steering system is connected to the upper end of this inner drill pipe, and the drill bit is connected to the lower end of the drill pipe.
  • the mandrel comprises means to exert lateral force on the inner drill pipe so as to deflect the drill direction as desired.
  • the inner drill pipe of the rotary steering system must allow passage of an auxiliary tool.
  • FIG. 4 a schematically a longitudinal cross-section of an embodiment of the rotary drill bit 410 of FIG. 1 is shown.
  • the drill bit 410 is shown in the wellbore 2, and is attached in this embodiment to the lower end of the bit shaft 410 of FIG. 3.
  • the bit body 205 of the drill bit 410 has a central longitudinal passage 420 for an auxiliary tool from the interior 207 of the tubing string 12 to the wellbore 1 exterior of the drill bit 410, as will be explained in more detail below.
  • Bit nozzles are arranged in the bit body 205. Only one nozzle with insert 209 is shown for the sake of clarity. The nozzle 209 is connected to the passageway 20 via the nozzle channel 209a.
  • the drill bit 410 is further provided with a removable closure element 435, which is shown in FIG. 4 in its closing position with respect to the passageway 420.
  • the closure element 435 of this example includes a central insert section 212 and a latching section 214.
  • the insert section 212 is provided with cutting elements 216 at its front end, wherein the cutting elements are arranged so as to form, in the closing position, a joint bit face together with the cutters 218 at the front end of the bit body 205.
  • the insert section can also be provided with nozzles (not shown). Further, the insert section and the cooperating surface of the bit body 205 are shaped suitably so as to allow transmission of drilling torque from the bit shaft 110 and bit body 205 to the insert section 212.
  • the latching section 214 which is fixedly attached to the rear end of the insert section 212, has substantially cylindrical shape and extends into a central longitudinal bore 220 in the bit body 205 with narrow clearance.
  • the bore 220 forms part of the passage 420, it also provides fluid communication to nozzles in the insert section 212.
  • the closure element 435 is removably attached to the bit body 205 by the latching section 214.
  • the latching section 214 of the closure element 435 comprises a substantially cylindrical outer sleeve 223, which extends with narrow clearance along the bore 220.
  • a sealing ring 224 is arranged in a groove around the circumference of the outer sleeve 223, to prevent fluid communication along the outer surface of the latching section 214.
  • Connected to the lower end of the sleeve 223 is the insert section 212.
  • the latching section 214 further comprises an inner sleeve 225, which slidingly fits into the outer sleeve 223.
  • the inner sleeve 225 is biased with its upper end 226 against an inward shoulder 228 formed by an inward rim 229 near the upper end of the sleeve 223.
  • the biasing force is exerted by a partly compressed helical spring 230, which pushes the inner sleeve 225 away from the insert section 212.
  • the inner sleeve 225 is provided with an annular recess 232 that is arranged to embrace the upper part of spring 230.
  • the outer sleeve 223 is provided with recesses 234 wherein locking balls 235 are arranged.
  • a locking ball 235 has a larger diameter than the thickness of the wall of the sleeve 223, and each recess 234 is arranged to hold the respective ball 235 loosely so that it can move a limited distance radially in and out of the sleeve 223.
  • Two locking balls 235 are shown in the drawing, however it will be clear that more locking balls can be arranged.
  • the locking balls 235 are pushed radially outwardly by the inner sleeve 225, and register with the annular recess 236 arranged in the bit body 205 around the bore 220. In this way the closure element 435 is locked to the drilling bit 310.
  • the inner sleeve 225 is further provided with an annular recess 237, which is, in the closing position, longitudinally displaced with respect to the recess 236 in the direction of the bit shaft 410.
  • the inward rim 229 is arranged to cooperate with a connection means 239 at the lower end of an opening tool 240.
  • the connection means 239 is provided with a number of legs 250 extending longitudinally downwardly from the circumference of the opening tool 240. For the sake of clarity only two legs 250 are shown, but it will be clear that more legs can be arranged.
  • Each leg 250 at its lower end is provided with a dog 251, such that the outer diameter defined by the dogs 251 at position 252 exceeds the outer diameter defined by the legs 250 at position 254, and also exceeds the inner diameter of the rim 229.
  • the inner diameter of the rim 229 is preferably larger or about equal to the outer diameter defined by the legs 250 at position 254, and the inner diameter of the outer sleeve 223 is smaller or approximately equal to the outer diameter defined by the dogs 251 at position 252.
  • the legs 250 are arranged so that they are inwardly elastically deformable as indicated by the arrows.
  • the outer, lower edges 256 of the dogs 251 and the upper inner circumference 257 of the rim 229 are beveled.
  • the outer diameter of the opening tool 240 is significantly smaller than the diameter of the bore 220.
  • the tubing string 12 can be used for progressing the wellbore 1 into the formation 2, when the MWD/LWD probe 355 hangs in the collar 351 as shown in FIG. 2, when the rotor 406 is arranged in the stator 408 of the mud motor 404 as shown in FIG. 3, and when the insert 435 is latched to the bit body 205 as shown in FIG. 4.
  • the tool assembly 160 would normally be stored at surface.
  • the tubing string 12 can thus be used to drill the wellbore 1 into a desired subsurface position.
  • the probe 355, the rotor 406 and the insert 435 together form a closure element for the passageway 20.
  • a situation can be encountered, which requires the operation of the tool assembly 160 in the wellbore 1 ahead of the drill bit 310. This will be referred to as a tool operating condition. Examples are the occurrence of mud losses which require the injection of fluids such as lost circulation material or cement, performing a cleaning operation in the open wellbore, the desire to perform a special logging, measurement, fluid sampling or coring operation, the desire to drill a pilot hole.
  • fluids such as lost circulation material or cement
  • the tubing string 12 is pulled up a certain distance to create sufficient space for at least part of the tool assembly at position 430, and the passageway is opened.
  • the MWD/LWD probe 355 and the rotor 406 can be retrieved to surface, such as by using a fishing tool with a connector means at its lower end that can be pumped down or upwardly through the drill string and can also be pulled up again by wireline. Retrieving of the MWD/LWD probe and the rotor can be done in consecutive steps.
  • the lower end of the probe can also be arranged so that it can be connected to the connection means 430 at the upper end of the rotor 406, so both can be retrieved at the same time.
  • the opening tool 240 can then be deployed, through the interior of the tubing string 12, so as to outwardly remove the closure element 435 from bit body 205.
  • the opening tool 240 is affixed to the lower end of the tool assembly 160.
  • the tool assembly 160 can be deployed from surface by pumping through the interior of the tubing string 12, with the transfer tool 338 connected to the upper end of the tool assembly 160 (the tool can be logging, as described above, as it is lowered to contact the BHA).
  • the tool assembly 160 passes though the tubing string 12 and the passageway 320 of the bottom hole assembly 8, i.e.
  • the recesses 237 register with the balls 235, thereby unlatching the closure element 435 from the bit body 205.
  • the closure element 435 is integrally pushed out of the bore 220.
  • the passageway 320 is opened.
  • the lower part of the tool assembly 160 at the upper end of the opening tool 240 enters the open wellbore 1 outside of the drill bit 410, and it can be operated there.
  • the tool assembly 160 is long enough so that it extends through the entire bottom hole assembly 8 and remains connected to the transfer tool 338 above the bottom hole assembly 8. This allows straightforward retrieval of the tool assembly 160 to the surface, by slickline, wireline or reverse pumping.
  • the wellbore 1 below the drill bit 310 may be surveyed by moving the entire tubing string 12 along the wellbore by reeling the reel (14 in FIG. 1).
  • FIG. 5 shows the lower end of the drill bit 310 in the situation that a logging tool 260, of which the lower part 261 has been passed through the passageway.
  • the closure element 435 has been outwardly removed from the closing position by the opening tool 240 disposed at the lower end of the logging tool 260.
  • a number of sensors and/or electrodes of the logging tool are shown at 266. They can be battery-powered, or can be powered by a turbine or through electrical power transmitted along a wireline extending to surface. Data can be stored in the tool or transmitted to surface.
  • the logging tool 260 further comprises a landing member (not shown) having a landing surface, which cooperates with a landing seat of the bottom hole assembly 8.
  • the drill bit 310 can for example have an outer diameter of 21.6 cm (8.5 inch), with a passageway of 6.4 cm (2.5 inch).
  • the lower part 261 of the logging tool which is the part that has passed out of the drill string onto the open wellbore, is in this case substantially cylindrical and has a relatively uniform outer diameter of 5 cm (2 inch).
  • the portion of the drill bit lowered beneath the tool assembly 160 can be used to continue to drill a smaller diameter bore hole for some distance below the bottom of the existing wellbore, with the sensors 266 in tool 260 continuing to measure and store and/or transmit measurement data as the smaller diameter borehole is being drilled.
  • Drilling power may be provided by an electrical connection (not described) to the surface and a downhole electric motor, or by an additional mud motor (not shown).
  • an electrical connection not described
  • a downhole electric motor or by an additional mud motor (not shown).
  • the same sensors in the tool assembly 160 can measure, store and/or transmit data as the tubing string 12 is inserted into and/or withdrawn from the wellbore.
  • the tool assembly 160 After the tool assembly 160 has been operated in the wellbore at 430, it can be retrieved into the tubing string 12 by pulling up the transfer tool 438. The closure insert 435 will then reconnect to the bit body 205. The opening tool 240 will disconnect from the insert 435, and the tool assembly 160 can be fully retrieved to the surface. Rotor 406 and MWD/LWD probe 355 can be lowered into the mud motor and MWD/LWD stator 408, respectively, so that the closure element is complete again, and drilling can be resumed. If a following tool operation condition occurs, the whole cycle can be repeated, wherein in particular a different tool assembly can be used. The flexibility gained in this way during a directional drilling operation is a particular advantage of the present embodiment.
  • the tubing string assembly includes a releasable tubing string interconnecting means for selectively interconnecting the first and second tubing string parts.
  • An auxiliary tool is provided for manipulating the second tubing string part.
  • the auxiliary tool can pass along the passageway in the first tubing string part to the second tubing string part.
  • the assembly further includes a tool-connecting means for selectively connecting the auxiliary tool to the second tubing string part, and an operating means for operating the tubing string-interconnecting means.
  • Wardley U.S. Pat. No. 6,443,247 discloses a casing drilling shoe adapted for attachment to a casing string.
  • the shoe comprises an outer drilling section constructed of a relatively hard material and an inner section made from a readily drillable material.
  • the shoe includes means for controllably displacing the outer drilling section to enable the shoe to be drilled through using a standard drill bit and subsequently penetrated by a reduced diameter casing string or liner.
  • the outer section may be made of steel and the inner section may be made of aluminium.
  • the drill bit (310 in FIG. 1) may be substituted by a drilling shoe as disclosed in the Wardley patent.
  • Such a drilling shoe may be rotated by an annular drilling motor. Such combination may be in substitution for all the components shown in FIGS. 1-5 between the lower end of the tubing string 12 and the drill bit 310.
  • the outer section of the Wardley-type drilling shoe is provided with one or more blades, wherein the blades are moveable from a first or drilling position to a second or displaced position.
  • the blades when the blades are in the first or drilling position they extend in a lateral direction to such extent as to allow for drilling to be performed over the full face of the shoe. This enables the casing shoe to progress beyond the furthest point previously attained in a particular well.
  • the means for displacing the outer drilling section may comprise of a means for imparting a downward thrust on the inner section sufficient to cause the inner section to move in a down-hole direction relative to the outer drilling section.
  • the means may include an obstructing member for obstructing the flow of drilling mud so as to enable increased pressure to be obtained above the inner section, the pressure being adapted to impart the downward thrust.
  • the direction of displacement of the outer section has a lateral component.
  • the check valve (10 in FIG. 1) includes a device for being selectively opened by passage therethrough of the tool string 160, such that the tool string 160 may be moved into the position below the bottom of the drill bit (310 in FIG. 1) as explained above.
  • An embodiment of a check valve having such device will now be explained with reference to FIGS. 6 and 7.
  • FIG. 6 shows the check valve open to passage of fluid therethrough.
  • FIG. 7 shows the valve when it is closed to fluid flow.
  • the check valve 10 may be formed from a lower mandrel 112 having an internal flow passage 16 and an upper mandrel 14 threadedly coupled to the lower mandrel 112. The threaded coupling is attained by corresponding mating threaded connections, shown respectively at 112A and 14A.
  • the upper mandrel 14 may include an internal fluid flow passage 32 and an upper threaded connection 34 for coupling to the lower end of the tubing string (12 in FIG. 1), or other component disposed at the lower end of the tubing string 12 (e.g., drill collars, MWD/LWD collars, steerable motor, etc.).
  • the lower mandrel 112 may include a lower threaded connection 18 for coupling to the drill bit (310 in FIG. 1).
  • the upper mandrel 14 includes a substantially cylindrical chamber therein 20 for receiving a sliding valve sleeve 22.
  • the valve sleeve 22 may be biased such as by a spring or the like (not shown) in the direction of the upper mandrel 14.
  • the upper mandrel 14 may include on its lower longitudinal end a shoulder 112B that stops the sleeve 22 from further longitudinal movement.
  • the sleeve 22 may include through the wall thereof one or more ports 24, 26 to enable fluid flow through the wall of the valve sleeve 22 when the ports 24, 26 are aligned with corresponding flow channels 28 formed into the wall of the upper mandrel 14.
  • the valve sleeve 22 will be moved into the lower or opened-to-flow position (FIG. 6) such that fluid may move from the upper mandrel 14, through the sleeve, through the channels 28 and into the lower mandrel 112.
  • the sleeve 22 includes a burst disk 30 at the upper end thereof that effectively seals the longitudinal passage through the interior of the sleeve 22.
  • the burst disk 30 is of any type known in the art and is ordinarily intended to rupture when a selected differential fluid pressure is applied thereto.
  • the burst disk 30 may be ruptured by the impact force of the tool string 160, thus enabling free passage of the tool string 160 through the valve sleeve 22. Absent impact of the tool string 160 on the rupture disk 30, the rupture disk 30 serves to seal the internal bore of the sleeve 22 such that the check valve operates conventionally.
EP06124022A 2006-11-14 2006-11-14 Clapet de fond de puits non-retour muni d'un disque de rupture Withdrawn EP1923535A1 (fr)

Priority Applications (1)

Application Number Priority Date Filing Date Title
EP06124022A EP1923535A1 (fr) 2006-11-14 2006-11-14 Clapet de fond de puits non-retour muni d'un disque de rupture

Applications Claiming Priority (1)

Application Number Priority Date Filing Date Title
EP06124022A EP1923535A1 (fr) 2006-11-14 2006-11-14 Clapet de fond de puits non-retour muni d'un disque de rupture

Publications (1)

Publication Number Publication Date
EP1923535A1 true EP1923535A1 (fr) 2008-05-21

Family

ID=37853031

Family Applications (1)

Application Number Title Priority Date Filing Date
EP06124022A Withdrawn EP1923535A1 (fr) 2006-11-14 2006-11-14 Clapet de fond de puits non-retour muni d'un disque de rupture

Country Status (1)

Country Link
EP (1) EP1923535A1 (fr)

Cited By (6)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
WO2013091107A1 (fr) * 2011-12-23 2013-06-27 Conrad Petrowsky Sous-ensemble de disque de sécurité combiné pour complétions de puits horizontal et vertical
WO2014003737A1 (fr) * 2012-06-27 2014-01-03 Halliburton Energy Services, Inc. Dispositif d'exclusion de fluide pour diagraphie dans des boues à base d'eau
WO2014210361A1 (fr) * 2013-06-28 2014-12-31 Epic Lift Systems Llc Piston d'ascension au gaz
US10316979B2 (en) 2014-09-10 2019-06-11 Armor Tools International Inc. Ceramic rupture dome for pressure control
CN113670789A (zh) * 2021-07-28 2021-11-19 金石钻探(唐山)股份有限公司 一种压水试验的方法及装置
US11680455B2 (en) 2018-11-13 2023-06-20 Rubicon Oilfield International, Inc. Three axis vibrating device

Citations (5)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US3698411A (en) * 1970-07-29 1972-10-17 Smith International Kelly foot valve
US3965980A (en) * 1975-02-21 1976-06-29 Smith International, Inc. Mud saver valve
WO1993011336A1 (fr) * 1991-11-30 1993-06-10 Appleton Robert P Clapet de retenue de la boue pour appareil de forage de puits
US20040118611A1 (en) * 2002-11-15 2004-06-24 Runia Douwe Johannes Drilling a borehole
US20050045327A1 (en) * 2003-09-03 2005-03-03 Wang David Wei Gravel packing a well

Patent Citations (5)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US3698411A (en) * 1970-07-29 1972-10-17 Smith International Kelly foot valve
US3965980A (en) * 1975-02-21 1976-06-29 Smith International, Inc. Mud saver valve
WO1993011336A1 (fr) * 1991-11-30 1993-06-10 Appleton Robert P Clapet de retenue de la boue pour appareil de forage de puits
US20040118611A1 (en) * 2002-11-15 2004-06-24 Runia Douwe Johannes Drilling a borehole
US20050045327A1 (en) * 2003-09-03 2005-03-03 Wang David Wei Gravel packing a well

Cited By (6)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
WO2013091107A1 (fr) * 2011-12-23 2013-06-27 Conrad Petrowsky Sous-ensemble de disque de sécurité combiné pour complétions de puits horizontal et vertical
WO2014003737A1 (fr) * 2012-06-27 2014-01-03 Halliburton Energy Services, Inc. Dispositif d'exclusion de fluide pour diagraphie dans des boues à base d'eau
WO2014210361A1 (fr) * 2013-06-28 2014-12-31 Epic Lift Systems Llc Piston d'ascension au gaz
US10316979B2 (en) 2014-09-10 2019-06-11 Armor Tools International Inc. Ceramic rupture dome for pressure control
US11680455B2 (en) 2018-11-13 2023-06-20 Rubicon Oilfield International, Inc. Three axis vibrating device
CN113670789A (zh) * 2021-07-28 2021-11-19 金石钻探(唐山)股份有限公司 一种压水试验的方法及装置

Similar Documents

Publication Publication Date Title
US7287609B2 (en) Drilling a borehole
US7708057B2 (en) Coiled tubing wellbore drilling and surveying using a through the drill bit apparatus
US8678109B2 (en) Intelligent controlled process for well lateral coring
US5488989A (en) Whipstock orientation method and system
US8210284B2 (en) Coring apparatus and methods to use the same
EP2491225B1 (fr) Systèmes et procédés de diagraphie de trous de forage par un train de tiges de forage
CA2514534C (fr) Outil de fond de puits a unite d'entrainement axiale
EP1210498B1 (fr) Navettes intelligentes permettant d'achever les puits de petrole et de gaz
EP2065553B1 (fr) Système et procédé pour forer des trous de forage latéraux
US7036610B1 (en) Apparatus and method for completing oil and gas wells
US20130292110A1 (en) Downhole apparatus, device, assembly and method
EP1923535A1 (fr) Clapet de fond de puits non-retour muni d'un disque de rupture
US20060124306A1 (en) Installation of one-way valve after removal of retrievable drill bit to complete oil and gas wells
US20160245068A1 (en) Pressure locking device for downhole tools
EP2132400B1 (fr) Ensemble de trépan et procédé d'exécution d'une opération dans un trou de forage
AU2021203534A1 (en) Multi-segmented plug
EP2867464B1 (fr) Outil de prélèvement d'échantillons de fluide
EP2867465B1 (fr) Outil de recharge de récipients de fluide

Legal Events

Date Code Title Description
PUAI Public reference made under article 153(3) epc to a published international application that has entered the european phase

Free format text: ORIGINAL CODE: 0009012

AK Designated contracting states

Kind code of ref document: A1

Designated state(s): AT BE BG CH CY CZ DE DK EE ES FI FR GB GR HU IE IS IT LI LT LU LV MC NL PL PT RO SE SI SK TR

AX Request for extension of the european patent

Extension state: AL BA HR MK RS

STAA Information on the status of an ep patent application or granted ep patent

Free format text: STATUS: THE APPLICATION HAS BEEN WITHDRAWN

18W Application withdrawn

Effective date: 20081107