Classifications

• • 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
  • E21B7/20—Driving or forcing casings or pipes into boreholes, e.g. sinking; Simultaneously drilling and casing boreholes
• • 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
  • E21B17/20—Flexible or articulated drilling pipes, e.g. flexible or articulated rods, pipes or cables
  • E21B17/206—Flexible or articulated drilling pipes, e.g. flexible or articulated rods, pipes or cables with conductors, e.g. electrical, optical
• • 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
  • E21B4/00—Drives for drilling, used in the borehole
  • E21B4/04—Electric drives
• • 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
  • E21B4/00—Drives for drilling, used in the borehole
  • E21B4/18—Anchoring or feeding in the borehole
• • E—FIXED CONSTRUCTIONS
  • E21—EARTH OR ROCK DRILLING; MINING
  • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
  • E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
  • E21B43/02—Subsoil filtering
  • E21B43/10—Setting of casings, screens, liners or the like in wells
  • E21B43/103—Setting of casings, screens, liners or the like in wells of expandable casings, screens, liners, or the like

Definitions

• the present invention relates to drilling a wellbore and to lining the wellbore without having to remove the drilling assembly from the wellbore. More particularly, the invention relates to a system of drilling a wellbore and of completing the well through the expansion of tubulars. More particularly still, the invention relates to the drilling of a wellbore and of lining the wellbore by expansion of one tubular into another to provide a sealed connection therebetween without having to pull the drilling assembly from the wellbore.
• ellbores are typically formed by drilling and thereafter lining a borehole with steel pipe called casing. The casing provides support to the wellbore and facilitates the isolation of certain sections of the wellbore adjacent hydrocarbon bearing formations.
• the casing typically extends down the wellbore from the surface of the well and the annulus between the outside of the casing and the borehole wall is filled with cement to permanently set the casing in the wellbore.
• additional strings of pipe are run into the well to that depth whereby the upper portion of the string of pipe (hereinafter referred to as "liner"), is overlapping the lower portion of the casing.
• the liner is then fixed or hung in the wellbore, usually by some mechanical slip means well known in the art. Emerging technology permits wellbore tubulars to be expanded in situ.
• the technology permits the physical attachment of a smaller tubular to a larger tubular by increasing the outer diameter of a smaller tubular by means of a radial force applied from within the smaller tubular.
• the expansion can be accomplished by a mandrel or a cone-shaped member urged through the tubular that is to be expanded or by any other known expander tool.
• the upper end of a liner can be expanded into the surrounding casing. In this manner, the conventional slip assembly and its related setting tools are eliminated.
• the liner is run into the wellbore on a run- in string with the expander tool disposed in the liner and connected thereto by a . temporary connection.
• the expander tool As the assembly reaches a predetermined depth whereby the top of the liner is adjacent a lower section of the casing, the expander tool is actuated and then, through rotational and/or axial movement of the actuated expander tool within the liner, the liner wall is expanded past its elastic limits and into contact with the wall of the casing. Rotation of the expander tool, is performed by rotating the run-in string or by utilizing a mud motor in the run-in string to transfer hydraulic power to rotational movement.
• the present invention relates to a method of drilling a second wellbore section from a first wellbore section that is lined with a tubular liner using a remotely controlled electrically powered drilling assembly that is suspended from a cable and of periodically interrupting the drilling operation to extend the tubular liner into the second wellbore section without having to pull the assembly from the wellbore.
• a method of drilling a second wellbore section from a first wellbore section that is lined with a tubular liner and of extending the tubular liner into the second wellbore section comprising: (a) drilling the second wellbore section from the first wellbore section using a remotely controlled electrically powered drilling assembly that is suspended from a cable that extends from the surface wherein the cable comprises an upper and a lower length of cable connected by a cable connection means and the drilling assembly comprises an expansion means, a traction means, and an electrically actuated drill bit and wherein electricity is transmitted to the assembly via at least one electrical wire and or segmented electrical conductor that extends from the surface to the assembly; (b) introducing an expandable liner pipe into the wellbore by disconnecting the cable connection means at the surface to separate the upper and lower lengths of cable, arranging the expandable liner pipe concentrically about the upper or lower length of cable, reconnecting the cable connection means to rejoin the upper and lower lengths of cable and running
• the method of the present invention may also be used to drill and to line a side-track wellbore or a lateral wellbore that is drilled from an existing wellbore.
• side-track wellbore is meant a branch of an existing wellbore where the existing wellbore no longer produces hydrocarbon fluid.
• the existing wellbore is sealed below the selected location from which the side-track wellbore is to be drilled, for example, with cement.
• lateral wellbore is meant a branch of an existing wellbore where the existing wellbore continues to produce hydrocarbon fluid.
• the side-track or lateral well may be drilled at any angle from the existing wellbore. Even in such wells, the wellbore is generally drilled to increasing depth and the terms "upper” and “lower” or “above” and “below” should be understood in this context. Similarly, a person skilled in the art would understand that although it would be preferable for the expandable liner pipe and cable to have the same axis, the term “concentric” is not used this strict mathematical sense and a degree of eccentricity can be tolerated or even desired.
• An advantage of the method of the present invention is that the cable traction means may be used to deliver expandable liner pipe to the second wellbore section without having to pull the assembly from the wellbore.
• a further advantage of the present invention is that the rock pore pressure is controlled by sealing the wellbore wall with the expandable liner pipe thereby allowing a simple single density mud to be employed during the drilling operation.
• the pressure of the simple single density mud may be increased as the second wellbore section is drilled to greater depth by pressurising the mud at the surface.
• Yet a further advantage of the process of the present invention is the potential reduction in the non-production drilling time (NPT) by reducing or at least mitigating wellbore stability problems (including loss circulation and stuck pipe) associated with prior art drilling and lining operations.
• NPT non-production drilling time
• the tubular liner may be a conductor, i.e. a short string of large diameter pipe that is used to keep the upper part of a wellbore open or a casing, i.e. a string of pipe, in particular, steel pipe, that is run from the surface into the wellbore.
• a conductor is drilled or pushed into a wellbore to a depth of 100 to 1000 feet (30.5 to 305 m). It is envisaged that a conductor may be drilled or pushed to the bottom of the first wellbore section.
• a conductor may be pushed into the upper part of the first wellbore section and a casing may then be run from the surface to the bottom of the first wellbore section.
• Drilling of the second wellbore section is then commenced using the drilling assembly suspended from the cable. Drilling of the second wellbore section is then interrupted and the cable connection means is disconnected to disconnect the upper and lower lengths of cable.
• a first expandable liner pipe is then arranged concentrically about the upper or lower length of cable, preferably the latter, the upper and lower lengths of cable are reconnected and the first expandable liner pipe is run into the wellbore along the cable supported on the cable traction means.
• first expandable liner pipe is then expanded into the tubular liner of the first wellbore section to form a sealed connection therebetween.
• the upper portion of the first expandable liner pipe may be expanded into either the lower portion of a conductor or into the lower portion of a casing that has been run into the first wellbore section through a conductor.
• the lower portion of the first expandable liner pipe is also expanded to extend the tubular liner into the second section of wellbore. Drilling of the second wellbore section is recommenced and is then interrupted to run a further expandable liner pipe into the wellbore along the cable supported on the cable traction means in a similar manner to the first expandable liner pipe.
• this further expandable liner pipe is expanded into the lower portion of the tubular liner to form a sealed connection therebetween while the lower portion of the further expandable liner pipe is expanded to further extend the tubular liner into the second wellbore section.
• This procedure may be repeated as desired until the drilling of the second wellbore section has been completed and the tubular liner extends to at or near the bottom of the second wellbore section.
• the assembly that is lowered into the wellbore suspended from the cable must have a maximum external diameter that is less than the internal diameter, d l5 of the tubular liner of the first wellbore section thereby allowing the drilling assembly to pass through the tubular liner to the bottom of the first wellbore section.
• the tubular liner of the first wellbore section has an inner diameter, d l5 of 5 to 10 inches (13 to 25 cm).
• the maximum outer diameter of the drilling assembly is at least 0.5 inches (1.3 cm), more preferably, at least 1 inch (2.5 cm) less than the inner diameter of the casing. It is therefore envisaged that the assembly may drill a second section of wellbore having a diameter, d , less than the internal diameter, d l3 of the tubular liner of the first wellbore section such that the tubular liner of the second wellbore section is of reduced internal diameter compared with the tubular liner of first wellbore section.
• the drill bit of the apparatus is provided with a “hole-opener".
• hole-opener is meant a device used to enlarge the size of a borehole, having cutting surfaces, for example, teeth, arranged on its outside circumference to cut the formation as it rotates.
• the hole- opener may be used to increase the diameter of the second wellbore section.
• the hole-opener may enlarge the second wellbore section during drilling of the second wellbore section, i.e. as the hole-opener is moved downwardly through the wellbore.
• the hole-opener may be actuated to enlarge the second wellbore section by interrupting the drilling step and moving the assembly upwardly through the open hole.
• Suitable hole-openers include conventional under reamers and eccentric drill bits.
• an under reamer is located above the drill bit of the assembly, preferably, immediately above the drill bit.
• the under reamer has radially extendible cutting surfaces that may be extended into contact with the wellbore wall to ream the wellbore. It is envisaged that the diameter of the second wellbore section may be enlarged to substantially the same diameter, d 3 , as the first wellbore section (where d 3 is the diameter of the first wellbore section prior to it being lined with the tubular liner).
• the tubular liner of the first wellbore section may be an expandable liner that is expanded against the wall of the first wellbore section using a conventional expansion tool.
• the expandable liner pipe and sealed connections between the liner pipe and the tubular liner may be expanded against the wellbore wall.
• the sealed connections between the liner pipes are formed by expanding an upper portion of liner pipe into the lower portion of the tubular liner, these connections are of double thickness. Accordingly, the internal diameter of the tubular liner is reduced at the connections.
• the tubular liner of the first wellbore section may be cemented into place in the wellbore with the thickness of the cement corresponding to the increased thickness of the sealed connections.
• cement is omitted from the lower portion of the first wellbore section, for example, the bottom 0.5 to 20 feet (0.15 to 6 m) to allow for accommodation of the first sealed connection.
• the lower portion of the first wellbore section may be provided with a crushable spacer, for example a spacer formed of expandable polystyrene.
• the sealed connections may be expanded against the wall of the second wellbore section with the portions of the liner pipe between the sealed connections being expanded to the same internal diameter as the sealed connections resulting in a true monobore well.
• This annular gap may be filled by pumping a cement into the wellbore in a conventional manner prior to expanding the liner pipe.
• the cement flows through the interior of the liner pipe and into the annular gap between the liner pipe and the wall of the wellbore.
• the liner pipe is then expanded from the bottom upwards thereby applying pressure to the cement that is present in the annular gap and forcing excess cement to flow upwardly through the annular gap and out from the top of the liner pipe into the wellbore. Once the cement has set, a pressure seal is formed between the expanded liner pipe and the cement.
• the second wellbore section may be reamed such that its diameter in the intervals where is its desired to form the sealed connections (cUL) is greater than the diameter in the intervals between the sealed connections (d 3 ) wherein the difference between the diameters & t -d 3 is sufficient to accommodate the increased thickness of the sealed connections and wherein d 3 is as defined above.
• the lower portion, for example, the bottom 0.5 to 20 feet (0.15 to 6 m) of the first wellbore section is also reamed to diameter &». Accordingly, both the sealed connections and the portions of liner therebetween may be expanded against the wellbore wall without any restriction in the internal diameter of the wellbore in the vicinity of the sealed connections resulting in a true monobore well.
• the first wellbore section is drilled in a conventional manner using a drill string having a drill bit provided with a hole-opener on the lower end thereof.
• the hole-opener is used to increase the diameter of the lower portion of the first wellbore section to diameter d*.
• Suitable hole-openers are as described above.
• a conductor is pushed or drilled into the upper part of the first wellbore section during the drilling of the first wellbore section.
• a casing is run from the surface to the bottom of the first wellbore section in a conventional manner such that the lower end of the casing lies in the reamed lower portion of the first wellbore section.
• the casing constitutes the tubular liner for the first wellbore section.
• the thickness of the layer of cement preferably corresponds to the difference between the diameters drd 3 .
• the reamed lower portion of the first wellbore section is provided with a crushable spacer, for example, a spacer formed of expandable polystyrene. This crushable spacer allows the sealed connection that is formed between the first expandable liner pipe and the casing to be expanded against the wall of the reamed lower portion of the first wellbore section.
• the casing of the first wellbore section may be an expandable casing that is expanded against the conductor and against the wall of the wellbore using a conventional expansion tool, for example an expandable mandrel in which case the crushable spacer may be omitted.
• the drilling assembly is then lowered to the bottom of the first wellbore section ' suspended on a cable and drilling of the second wellbore section is commenced by rotating the drill bit.
• the drill bit may be configured to drill a hole of greater diameter than its initial diameter.
• the bit may be a bi-centre bit or an expandable bit such that the bit may pass through the casing of the first wellbore section and then be utilised to drill a bore of larger diameter than the internal diameter of the casing of the first wellbore section.
• the drill bit of the assembly is provided with a hole- opener, for example, an under reamer.
• the diameter of the second wellbore section is less than the internal diameter of the casing that constitutes the tubular liner of the first wellbore section.
• the second wellbore section is preferably reamed to a larger diameter by radially extending the cutters of the hole-opener into engagement with the wall of the second wellbore section.
• the second wellbore section may be enlarged until its diameter corresponds to that of the reamed lower portion of the first wellbore section.
• the diameter of the second wellbore section may be substantially uniform along the entire length thereof.
• the second wellbore section may be enlarged such that its diameter alternates between longer intervals having a diameter that corresponds to the diameter / of the un-reamed upper portion of the first wellbore section and shorter intervals having a diameter that corresponds to that of the reamed lower portion of the first wellbore section.
• the difference between the diameters of the shorter and longer intervals is sufficient to accommodate the sealed connections.
• the shorter intervals that are reamed to a larger diameter to accommodate the sealed joints have a length of from 0.5 to 20 feet (0.15 to 6 m) (i.e. the preferred length of the upper portion of the expandable liner pipe that is expanded into the tubular liner to form the sealed joint).
• the longer intervals correspond to the length of the lower portion of the expandable liner pipe that is expanded to extend the tubular liner into the second wellbore section.
• the length of the each liner pipe that is run into the wellbore along the cable is dependent upon parameters such as the geology of the formation, the pore pressure of the formation, wellbore stability and any loss of drilling fluid to the formation (lost circulation) and may be in the range 10 to 1000 feet (3 to 305 m).
• the expandable liner pipe may be formed of metal, for example, a low carbon steel or any other steel alloy, or from an expandable plastic material. When the expandable liner pipe is metal and is expanded against the wall of the second wellbore section, a metal to rock seal is obtained.
• the expandable liner pipe is provided with a coating of a resilient material, preferably an elastomeric material, to provide an improved seal with the rock.
• a resilient material preferably an elastomeric material
• the elastomeric material is resistant to the well environment, i.e. temperature, pressure, well fluids, and the like.
• the elastomeric material is selected from rubber (for example, silicone rubber), polymers of ethyl ene-propylene diene monomer (EPDM), polytetrafluoroethylene, polyphenylene sulfide, and perfluoroelastomers.
• the thickness of the coating of resilient material is in the range 0.05 to 2 inches (0.13 to 5 cm), for example, about 0.5 inch (1.3 cm).
• the thickness of the wall of the expandable liner pipe decreases as it is expanded.
• the required thickness of the wall after expansion is a function of the diameter of the wellbore and the yield and tensile strength of the metal forming the expandable liner pipe.
• the thickness of the wall of the expanded metal liner pipe is in the range 0.25 to 1 inches (0.64 to 2.54 cm) for an expanded pipe having an internal diameter in the range 6 to 8 inches (15 to 20 cm).
• the expandable liner pipe may be capable of being deformed such that in its deformed state the liner pipe can pass through a restriction in a wellbore to the location where the liner pipe is to be expanded to extend the tubular liner of the wellbore.
• the liner pipe Once at the desired location in the wellbore, the liner pipe may be reformed into a substantially tubular shape having an outer diameter greater than the minimum restriction in the wellbore and the reformed pipe may then be expanded to extend the tubular liner without exceeding the maximum expansion ratio for the expandable liner pipe.
• the maximum expansion ratio for the reformed pipe is generally about 30%.
• the expansion ratio from the deformed to the expanded state may be in the range 30 to 100%
• the liner pipe is deformed into a longitudinally corrugated pipe. It is also envisaged that the liner pipe may be deformed into any other shape that is capable of passing through the minimum restriction in the wellbore. Suitably, the liner pipe may be deformed to a size smaller than the minimum restriction in the wellbore using a set of rollers located above the wellhead.
• the reformable and expandable liner pipe is provided with a coating of a resilient material, as described above.
• the liner pipe can comprise sections of pipe connected together by connections, such as, for example, screw connections. Generally, the whole of the liner pipe, including such screwed connections are expanded.
• the deformed metal liner pipe may be reformed and expanded using the expansion means of the assembly.
• the expansion means of the assembly may reform the entire pipe prior to expanding the pipe to extend the tubular liner of the wellbore.
• the expansion means reforms and expands the deformed metal liner pipe in a single operation.
• the liner pipe may be expanded only between any screw connections in which case it is preferred that the portions of the liner pipe that form any such screwed connections are substantially tubular having an outer diameter that allows the connections to pass through the tubular liner of the first wellbore section.
• the drilling assembly is lowered into the wellbore suspended from a cable.
• the cable is provided with a plurality of cable connection means spaced apart along the length thereof, for example, at 250 to 1000 feet (76 to 305 m) intervals. Accordingly, as the second wellbore section is drilled to a greater length, the upper and lower lengths of the cable may be disconnected using the closest connection means to the surface or a cable connection means that has yet to enter the wellbore.
• the cable is a reinforced cable, for example, a reinforced steel cable.
• the cable may be connected to the drilling assembly by means of a connector, preferably, a releasable connector.
• the cable encases one or more wires and/or segmented conductors for transmitting electricity or electrical signals from the surface to the assembly (hereinafter "conventional cable").
• the assembly may be suspended from a conventional reinforced cable with electricity and/or electrical signals being transmitted from the surface to the assembly via a separate electrical cable.
• the cable from which the drilling assembly is suspended may also be a "hybrid cable” comprising tubing suitable for conveying a fluid wherein at least one electrical conductor wire and/or segmented electrical conductor is embedded in the wall of the tubing.
• the hybrid cable comprises an inner tube, a layer of an insulation material having at least one electrical conductor wire and/or segmented conductor embedded therein, an intermediate fluid barrier layer and an outer flexible protective sheath.
• the inner tube and outer intermediate fluid barrier layer are comprised of steel.
• the insulation material is a flexible material, preferably a plastic or rubber material.
• the outer protective sheath is steel braiding.
• the electrical conductor wire(s) and or segmented conductor(s) embedded in the layer of insulation material are coated with an electrical insulation material.
• the internal diameter of the inner tube of the hybrid cable is in the range 0.2 to 5 inches (0.5 to 13 cm), preferably 0.3 to 1 inches (0.8 to 2.54 cm).
• the assembly that is suspended from the cable comprises an elongate housing, preferably, a tubular housing.
• the tubular housing is connected to the cable via a releasable connection means.
• an electric motor and a drive means for the drill bit are located within the housing of the assembly.
• the electric motor powers the drive means for the drill bit with electricity being transmitted to the electric motor from the surface via an electrical conductor wire and/or a segmented conductor that is either embedded in the cable from which the assembly is suspended or in a separate electric cable.
• the means for driving the drill bit also drives the optional hole-opener.
• the means for driving the drill bit may be a rotor.
• the housing of the assembly may also be provided with an electrically actuated traction means for providing thrust to the drill bit.
• the housing of the assembly has a fluid passage that is in fluid communication with ports in the drill bit and with ports in the optional hole-opener.
• the housing is provided with a pumping means, for example, a suction pump, that is used to pass a fluid through the passage in the housing to the ports in the drill bit (and the ports in optional hole-opener).
• the fluid cools the cutting surfaces of the drill bit (and optional hole-opener) and also transports drill cuttings away from the cutting surfaces entrained in the fluid.
• the pumping means is electrically powered with electricity being transmitted to the pumping means via an electrical conductor wire and/or a segmented conductor.
• a drilling mud is pumped through the passage of the drilling assembly and out over the cutting surfaces of the drill bit via the pumping means.
• the drilling mud may be pumped from the surface through the inner tube of the hybrid cable and through the passage in the assembly to the ports in the drill bit and out over the cutting surfaces.
• the inner tube of the hybrid cable is in fluid communication with the passage in the housing of the assembly.
• the drilling mud having drill cuttings entrained therein then flows back to the surface over the outside of the assembly and through the annulus formed between the wellbore wall and the hybrid cable ("conventional circulation" mode).
• the drilling mud may be passed to the drilling assembly through the annulus formed between the hybrid cable and the wall of the wellbore and an entrained cuttings stream may be transported away from the drilling assembly through the inner tube of the hybrid cable (“reverse circulation" mode).
• the assembly is provided with at least one inlet for the drilling mud that is in fluid communication with the ports in the drill bit (and optional hole-opener) and also with the inner tube of the hybrid cable.
• the passage in the housing of the assembly has a branch point with a first branch passage that is in fluid communication with the ports and a second branch passage that is in fluid communication with the inner tube of the hybrid cable.
• a drilling mud may be pumped from the surface to the bottom of the wellbore via a hydraulic line (coiled tubing or a jointed pipe string). This hydraulic line is preferably arranged in parallel with the conventional cable rather than concentrically about the conventional cable.
• this hydraulic line is in fluid communication with a passage in the housing of the assembly with the drilling mud flowing through this passage and out through ports in the drill bit (and the optional hole-opener).
• the drilling mud then flows back to the surface over the outside of the assembly and through the interior of the tubular liner.
• the drilling assembly is used to drill a second wellbore section through a producing formation
• the cutting surfaces on the drill bit may be cooled by the fluids that are produced from the formation into the wellbore and that drill cuttings may be transported away from the cutting surfaces entrained in the produced fluid. Accordingly, there is no requirement to pass a drilling mud from the surface to the drilling assembly.
• produced fluid is meant produced liquid hydrocarbons and/or produced water, preferably produced liquid hydrocarbons.
• hydrocarbon fluid may to be produced from the wellbore during drilling of the section wellbore section.
• the pressure of the hydrocarbon-bearing formation may be sufficiently high that the produced fluid having drill cuttings entrained therein flows to the surface by means of natural energy.
• the wellbore may be provided with artificial lift.
• pumping means and fluid passage through the assembly may be omitted.
• the assembly is provided with a pumping means for drawing produced fluids through an inlet in the housing and through a passage in the assembly that is in fluid communication with ports in the drill bit (and optional hole-opener).
• the method of the present invention may be also be used to drill a new section of wellbore from a selected location in an existing cased wellbore that has a hydrocarbon fluid production conduit arranged in sealing relationship with the wall of the casing.
• the casing of the existing wellbore constitutes the tubular liner.
• the new wellbore section may be an extension of the existing wellbore or a side track wellbore or lateral wellbore. Accordingly, it is preferred that the drilling assembly and the expandable liner pipe are capable of passing into the wellbore through the production conduit. This is advantageous in that there is no requirement to pull the production conduit from the wellbore.
• a production conduit has an inner diameter of 2.5 to 8 inches (6.4 to
• the maximum outer diameter of the drilling assembly and of the expandable liner pipe is at least 0.5 inches (1.3 cm), more preferably, at least 1 inch (2.5 cm) less than the inner diameter of the production conduit.
• the drill bit of the assembly is provided with a hole- opener, thereby allowing the new wellbore section that is drilled from the selected location to be enlarged to a greater diameter than the inner diameter of the production conduit.
• the new wellbore section is enlarged to substantially the same diameter as the diameter of the existing wellbore.
• the expandable liner pipe is a deformed expandable liner pipe of the type discussed above, thereby allowing the liner pipe to be expanded to extend the tubular liner without exceeding its maximum expansion ratio.
• the drilling assembly is provided with an electrically operated steering means, for example, a steerable joint, which is used to adjust the trajectory of the second wellbore section as it is being drilled.
• This steering means is electrically connected to equipment at the surface via an electrical conductor wire or a segmented conductor embedded in the cable from which the assembly is suspended or in a separate electrical cable.
• the drilling assembly may be provided with sensors which are electrically connected to recording equipment at the surface via an electrical conductor wire or segmented electrical conductor embedded in the cable from which the assembly is suspended or in a separate electrical cable.
• the sensors are located in proximity to the cutting surfaces on the drilling assembly. If desired, sensors may also be located along the cable. Such sensors may, for example, include at least one location sensor.
• the drilling assembly additionally comprises an electrically powered traction means for displacing the drilling assembly within the wellbore.
• the traction means may be used to advance the drilling assembly through the second wellbore section as it is being drilled, to take up the reactive torque generated by the means for driving the drill bit (and the optional hole-opener), to move the assembly upwardly through the wellbore, and to move the- assembly through the expandable liner pipe so that the expansion means expands the liner pipe. Electricity is transmitted to the traction means via an electrical conductor wire and/or segmented conductor encased in the cable from which the assembly is suspended or encased in a separate electrical cable.
• the traction means of the assembly comprises a first (upper) slip and a second (lower) slip that are connected either directly or indirectly by a piston in such a way that operation of the piston can move the slips towards or away from each other.
• the piston of the traction means comprises a cylinder that fits within a tube in which it moves up and down. This traction means may be operated to move the assembly upwardly through the wellbore by setting the upper slip to grip the inner wall of the tubular liner or open hole, unsetting the lower slip, moving the cylinder of the piston such that the second (lower) slip is moved upwardly towards the first (upper) slip, setting the second (lower) slip and unsetting the first (upper) slip.
• the cylinder is then moved back to its original position within the tube moving the first (upper) slip away from the second (lower) slip.
• the first (upper) slip is then set and the second (lower) slip unset.
• This operation may be repeated a plurality of times to move the assembly upwards in the wellbore.
• the traction means may also be operated to move the assembly downwardly through the wellbore by setting the lower slip and moving the cylinder of the piston to move the first (upper) slip towards the second (lower) slip, setting the upper slip, unsetting the lower slip and moving the cylinder to move the second (lower) slip away from the first (upper) slip and then the second (lower) slip is set and the first (upper) slip unset.
• the traction means of the assembly may comprise wheels or rollers which engage with and move the drilling assembly over the wall of the open hole or over the wall of the tubular liner.
• the cable traction means of the drilling assembly that is used to run the expandable liner pipe into the wellbore supports the expandable liner pipe and moves it along the cable, i.e. through the wellbore relative to the cable.
• the cable traction means is preferably provided with wheels or rollers that run along the cable but may instead, or in addition, have wheels or rollers that run against the tubular liner of the wellbore.
• the cable may pass through the traction means and the traction means extends beyond the upper end of the expandable liner pipe so that the wheels or rollers can run against the tubular liner.
• the cable traction means is electrically powered.
• the cable traction means is inductively coupled to the cable (where the cable has at least one electrical wire or segmented electrical cable).
• the cable traction means may be powered by a second electrical cable that extends to the surface.
• the cable traction means is provided with a radially extendible gripping member, preferably, an electrically powered radially extendible gripping member, that may be actuated for gripping the internal wall of the expandable liner pipe.
• the gripping member comprises at least one radially extendible "slip” that has teeth or other gripping elements.
• the cable traction means is provided with a plurality of "slips", preferably 2 to 4 slips. Suitable "slips" for use with the liner pipe would be well known to the person skilled in the art.
• the slips are moveable over the inner surface of the liner pipe. When the cable traction means has run a liner pipe from the surface to the bottom of the cable, the slips may be used to move the liner pipe downwardly through the wellbore with respect to the cable traction means so that the liner pipe is disposed concentrically about the drilling assembly and held by slips or a stop on the drilling assembly.
• the slips of the cable traction means may then be unset and the cable traction means may be moved upwardly along the cable.
• sensors are provided on the drilling assembly and optionally on the traction means. The sensors can be used to ensure that the liner is supported on the assembly at the desired location in the wellbore with the upper portion of the liner pipe overlapping the lower portion of the tubular liner and the lower portion of the liner pipe extending into the open hole.
• the expansion means may be an expandable packer.
• the length of the expandable packer may correspond to the length of the liner pipe so that the expandable packer is capable of simultaneously expanding the entire expandable liner pipe.
• the expandable packer may also have a length that is substantially less than the length of the expandable liner pipe.
• the expandable packer may be moved downwardly through the liner pipe to expand the liner pipe in stages.
• the expandable packer is first inflated to expand the upper portion of the liner pipe into the tubular liner to form a sealed joint therebetween.
• the packer is then deflated and is moved downwardly through the expandable liner pipe until the packer is arranged immediately below the sealed joint.
• the packer is then inflated to expand a further portion of the liner pipe before being deflated and this procedure is repeated until the entire liner pipe has been expanded.
• the traction means of the assembly may move the assembly and hence the expandable packer downwardly through the wellbore.
• the length of the open hole is controlled so that when the expandable packer is located in the upper portion of the expandable liner pipe, the drill bit is located at the bottom wellbore.
• the deflated packer may be moved through the liner pipe by actuating the drill bit to drill a further portion of the second wellbore and periodically interrupting the drilling operation to inflate the packer thereby expanding a portion of the liner pipe.
• the expansion means may also be an expandable mandrel that is disposed about the tubular housing of the assembly and is moveable from an upper to a lower position with respect to the housing of the assembly.
• the mandrel is initially located at its upper position with respect to the housing of the assembly, above the expandable liner pipe that is supported by the assembly.
• the mandrel is then expanded and is moved downwardly through the expandable liner pipe with respect to the housing of the assembly.
• the mandrel may be moved downwardly through the expandable liner pipe with respect to the housing via an electrically driven screw mechanism.
• the bottom of the expandable liner pipe is supported by the assembly.
• the mandrel may be in a fixed position with respect to the assembly, with drilling of a further portion of the second wellbore section causing the mandrel to move downwardly through the expandable liner pipe.
• the radially expandable gripping means of the assembly is retracted to enable the mandrel to move downwardly through the liner pipe as the further portion of the second wellbore section is being drilled.
• the expandable liner pipe may also be expanded using an electrically powered rotatable expansion means having at least one radially extendible member, for example, radially extendible rollers.
• the radially extendible member is electrically actuated. Electricity may be transmitted to the rotatable expansion means via an electrical conductor wire or segmented conductor encased in the cable from which the assembly is suspended or via a separate electric cable.
• the rotatable expansion means expands the expandable liner pipe by extending the radially extendible member into engagement with the inner wall of the expandable liner pipe and applying pressure, to the liner by gradually extending the extendible member whilst rotating the expansion means.
• the expansion means is provided with an electrically powered mechanism for radially extending and retracting the extendible elements.
• the expansion means may be rotatable with respect to the housing of the assembly. Alternatively, the entire assembly may be rotated to rotate the expansion means.
• the length of the open hole may be controlled so that when the drill bit is located at the bottom of the wellbore, the rotatable expansion means is located at the top of the expandable liner pipe. Accordingly, the rotatable expansion means may be moved downwardly through the liner pipe as the drill bit drills a further portion of the second wellbore section.
• the assembly is provided with sensors for monitoring the expansion of the pipe and the position of the expansion means in the wellbore.
• the cable traction means is actuated to collect a further section of liner pipe from the surface during the expansion operation so that the method of drilling and lining the wellbore becomes a seamless operation.
• the liner pipe may be introduced from the surface into the wellbore using a lubricator.
• lubricator is well known to the person skilled in the art, and means a specially fabricated length of casing or tubing that is arranged at the surface and is used to run tools into a wellbore. Typically, the lubricator is located immediately above a surface valve that is used to seal off the wellbore.
• a method of drilling a second wellbore section from a first wellbore section that is lined with a tubular liner and of extending the tubular liner into the second wellbore section comprising: (a) drilling the second wellbore section from the first wellbore section using a drilling assembly suspended from the lower end of a cable that encases at least one electrical wire or segmented electrical conductor wherein the assembly comprises an expansion means, an electric motor, a drive means and a drill bit, the cable extends from a surface hoist means through a lubricator and a surface valve into the wellbore and is provided with at least one releasable cable connection means and with a cable traction means that is moveable along the length of the cable, the method comprising: (b) interrupting drilling of the second wellbore section, actuating the hoist means to pull the cable and hence the assembly upwardly through the wellbore until the cable connection means is positioned within the
• the external diameter of the expandable liner pipe will be limited by the internal diameter respectively of the lubricator. It is envisaged that the length of the liner pipe may be limited by the length of the lubricator.
• the wellbore may be provided with a downhole valve. This downhole valve is closed before disconnecting the lubricator and cable connection means. A string of liner pipe is then arranged concentrically about the lower end of the cable and is lowered into the wellbore in a conventional manner before actuating the cable traction means to grip the internal wall of the liner string.
• the drilling assembly may be provided with a radially extendible cutter for cutting a section of liner from the liner pipe and that this cut section of liner pipe is then expanded to form a sealed joint with the tubular liner and to extend the tubular liner.
• the cut section of liner is supported on the assembly prior to being expanded using the expansion means of the assembly.
• the drilling operation is then recommenced to drill a further section of liner before interrupting the drilling operation to cut a further section of liner from the liner pipe to further extend the tubular liner.
• the cable connection means may be provided with a passage so that fluid, for example, drilling mud may flow through the cable connection means.
• the cable connection means may be provided with an outlet for the fluid.
• an apparatus for drilling and lining a wellbore comprising a remotely controlled electrically powered drilling assembly suspended from a cable having at least one electrical wire and/or segmented electrical conductor embedded therein for transmitting electricity or electrical signals from the surface to the assembly wherein the assembly comprises an expansion means and an electrically driven drill bit and the cable is provided with a traction means that is moveable along the cable for delivering an expandable liner pipe from the surface to the assembly.
• Figure 1 is a schematic cross-section of apparatus for use in the method of the present invention
• Figures 2 to 10 are schematic cross-sectional drawings illustrating the method of the present invention
• Figures 11 and 12 are schematic cross-sectional drawings illustrating the use of an expandable packer to expand the expandable liner pipe
• Figures 13 and 14 are schematic cross-sectional drawings illustrating the use of a radially expandable mandrel to expand the expandable pipe.
• the apparatus suspended from a hybrid cable 1.
• the apparatus comprises an expansion means 2, a traction means 3, a pumping means 4, an electric motor 5, a drive means (not shown) and a drill bit 6.
• the electric motor 5 powers the drive means that rotates the drill bit 6.
• the traction means 3 comprises a first slip 7 and a second slip 8 connected by a piston 9 and provides the necessary thrust to the drill bit.
• a first wellbore section 10 has been drilled through a subterranean formation and a casing (tubular liner) 11 has been run into the bottom thereof in a conventional manner.
• Drilling of a second wellbore section 12 from the first wellbore section 10 is commenced using the assembly of Figure 1 suspended from a hybrid cable.
• the hybrid cable comprises an upper length 13 and lower length 14 of cable joined via a releasable connection means 15.
• the hybrid cable passes from a surface winch means 16 through a lubricator 17 and valve 18 into the wellbore.
• the drive means is actuated such that the drill bit begins to drill the second wellbore section.
• Figure 3 shows the second wellbore section drilled to a greater depth.
• the hybrid cable has been partially pulled from the wellbore using the winch means 16 until the cable connection means 15 lies within the lubricator 17.
• the surface valve 18 is then closed.
• the lubricator 17 and cable connection means 15 have been disconnected and the lubricator 17 and the upper length 13 of the hybrid cable have been lifted away from the surface valve 18.
• An expandable liner pipe 19 has been arranged concentrically about the lower length 14 of the hybrid cable supported on a traction means 20 that is moveable along the cable (“cable traction means").
• the lubricator 17 has been lowered over the surface valve and the cable connection means 15 has been reconnected.
• the lubricator is then reconnected as shown in Figure 7.
• the cable traction means 20 is disposed in the annular space between the hybrid cable and the expandable liner pipe 19.
• the cable traction means 20 is provided with an external gripping member (not shown) that grips the inner wall of the liner pipe 19.
• the cable traction means 20 is also provided with tractor wheels (not shown) that are movable over the outer surface of the hybrid cable.
• the cable traction means 20 is electrically powered and is preferably inductively coupled to the hybrid cable.
• the liner pipe moves downwardly through the wellbore until the liner pipe lies immediately above the assembly, as shown in Figure 8.
• the expandable liner pipe 19 is then walked downwardly through the wellbore with respect to the cable traction means by moving the external gripping member over the internal surface of the liner pipe until the upper portion of the expandable liner pipe 19 overlaps the lower portion of the casing 11 of the first wellbore section 10 and the lower portion of the expandable liner pipe 19 extends into the open hole 12.
• the liner pipe is now arranged concentrically about the assembly.
• the expansion means of the assembly is radially expanded to expand the upper portion of the expandable liner pipe 19 into the lower portion of the casing 11 (the tubular liner for the first wellbore section) to form a sealed joint therebetween and to expand the lower portion of the expandable liner pipe to extend the tubular liner into the second wellbore section.
• the expansion means is then radially retracted as shown in Figure 9.
• the cable traction means 20 is moved upwardly along the cable 14 as shown in Figure 10.
• FIGS 11 and 12 illustrate an assembly according to the present invention comprising a radially expandable packer 21.
• the packer 21 may be hydraulically expanded.
• the lower gripping member 8 of the traction means 3 is radially extended to grip the wall 22 of the wellbore.
• the expandable liner pipe 19 is supported on the assembly.
• the expandable packer is initially located at the top of the liner pipe so that a sealed joint 23 is formed between the liner pipe 19 and the tubular wellbore liner 24 upon expansion of the packer 21.
• the packer is then retracted and the fraction means actuated to move the assembly downwardly through the wellbore until the packer is located immediately below the expanded section of the liner pipe.
• the packer is then expanded to expand a further section of liner pipe and the above procedure is repeated until the entire liner pipe has been expanded.
• Figures 13 and 14 illustrate as assembly according to the present invention comprising a radially expandable mandrel 25. Initially, the expandable mandrel is located above the expandable liner pipe 19 with the liner pipe supported on the assembly above the traction means 3.
• the mandrel 25 is expanded as shown in Figure 14 and is moved downwardly through the expandable liner pipe 19 as the drill bit 6 extends the wellbore. Simultaneously, the traction means 3 is operated to move the assembly through the wellbore. The traction means 3 also provides thrust to the drill bit 6.

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• 2003
  • 2003-12-22 GB GBGB0329712.4A patent/GB0329712D0/en not_active Ceased
• 2004
  • 2004-11-25 EP EP04798682A patent/EP1702133B1/de not_active Not-in-force
  • 2004-11-25 US US10/584,469 patent/US20070144784A1/en not_active Abandoned
  • 2004-11-25 WO PCT/GB2004/004986 patent/WO2005061835A1/en active IP Right Grant
  • 2004-11-25 DE DE602004009965T patent/DE602004009965D1/de active Active
  • 2004-11-25 CA CA002550194A patent/CA2550194A1/en not_active Abandoned
  • 2004-11-25 AT AT04798682T patent/ATE377692T1/de not_active IP Right Cessation

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