WO2016148682A1 - Forage avec un appareil de tubage, procédé et système - Google Patents

Forage avec un appareil de tubage, procédé et système Download PDF

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Publication number
WO2016148682A1
WO2016148682A1 PCT/US2015/020723 US2015020723W WO2016148682A1 WO 2016148682 A1 WO2016148682 A1 WO 2016148682A1 US 2015020723 W US2015020723 W US 2015020723W WO 2016148682 A1 WO2016148682 A1 WO 2016148682A1
Authority
WO
WIPO (PCT)
Prior art keywords
underreamer
casing
pistons
extended position
cutting
Prior art date
Application number
PCT/US2015/020723
Other languages
English (en)
Inventor
Bo Gao
John Gerard Evans
Mark Lance HAIRE
Original Assignee
Halliburton Energy Services, Inc.
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 Halliburton Energy Services, Inc. filed Critical Halliburton Energy Services, Inc.
Priority to PCT/US2015/020723 priority Critical patent/WO2016148682A1/fr
Publication of WO2016148682A1 publication Critical patent/WO2016148682A1/fr

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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
    • E21B10/00—Drill bits
    • E21B10/26—Drill bits with leading portion, i.e. drill bits with a pilot cutter; Drill bits for enlarging the borehole, e.g. reamers
    • E21B10/32—Drill bits with leading portion, i.e. drill bits with a pilot cutter; Drill bits for enlarging the borehole, e.g. reamers with expansible cutting tools
    • E21B10/322—Drill bits with leading portion, i.e. drill bits with a pilot cutter; Drill bits for enlarging the borehole, e.g. reamers with expansible cutting tools cutter shifted by fluid pressure
    • 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

Definitions

  • cemented casing is used in the borehole to provide structural support for the borehole in unstable geological formations in addition to sealing the borehole.
  • the casing may be inserted after the drill string has been removed or the casing may be inserted as part of the drilling operation (i.e., drilling with casing (DWC) or casing while drilling (CWD)).
  • DWC and CWD operations may reduce operation time by reducing or eliminating the need to drill with drill pipe, remove the drill pipe, and insert the casing into the wellbore.
  • limitations to these operations including limited torque at the casing connections and possible poor quality of the wellbore integrity.
  • FIG. 1 is a diagram showing an end view of an example DWC apparatus with underreamer cutting pistons in a retracted configuration, according to aspects of the present disclosure.
  • FIG. 2 is a cross-sectional diagram showing an example DWC apparatus with underreamer cutting pistons in the retracted configuration, according to aspects of the present disclosure.
  • FIG. 3 is a diagram showing an end view of an example DWC apparatus with underreamer cutting pistons in an extended configuration, according to aspects of the present disclosure.
  • FIG. 4 is a cross-sectional diagram showing an example DWC apparatus with underreamer cutting pistons in the extended configuration, according to aspects of the present disclosure.
  • FIG. 5 is a flowchart of an example method for a DWC operation, according to aspects of the present disclosure.
  • FIG. 6 is a diagram showing an example drilling system, according to aspects of the present disclosure.
  • FIG. 7 is a block diagram of an example system operable to execute the methods herein, according to aspects of the present disclosure.
  • the DWC apparatus described herein provides the ability to enlarge a wellbore diameter, during a drilling operation, beyond the diameter of the casing drill bit. This may provide a higher quality of wellbore integrity, enhance wellbore conditions for primary cementing, and save the time that might otherwise be taken up with extracting the bottom hole assembly after drilling.
  • drill pipe is hollow, relatively thin- walled, steel piping that is used on drilling rigs and horizontal drilling to facilitate the drilling of a wellbore.
  • Drill pipe is a portion of the overall drill string.
  • the drill string includes both drill pipe and the bottom hole assembly (BHA) which is the tubular portion closest to the bit.
  • BHA bottom hole assembly
  • Casing is larger diameter, thicker walled pipe that is conventionally assembled and inserted into a recently drilled section of a borehole and typically held into place with cement.
  • FIG. 1 is a diagram showing an end view of an example DWC apparatus 150 with underreamer cutting pistons in a retracted configuration, according to aspects of the present disclosure.
  • the DWC apparatus includes a drill bit 100 that is disposable. Once the wellbore is drilled by the drill bit 100 during a DWC operation, the drill bit remains downhole with the rest of the DWC apparatus 150.
  • a disposable drill bit may be defined as a drill bit that includes a built-in casing connection instead of a drill pipe connection such that they are permanently attached to the casing (i.e., non-retrievable). The casing connection cannot connect to a drill pipe connection.
  • the casing connection of the disposable drill bit is different from the pipe connection.
  • Casing threads match the casing size and have a conventional nut and bolt type thread taper (e.g., casing thread taper).
  • Casing connections are designed to be screwed together once and not removed.
  • a casing connection may be configured such that it conventionally connects only to casing and not to a drill string as in a conventional, non-disposable drill bit.
  • Drill pipe threads e.g., drill pipe connection
  • the drill pipe threads also are more rounded than casing threads.
  • FIG. 1 also shows section line A-A' that bisects the end of the apparatus.
  • the cross-sectional view of the apparatus along this section line is illustrated in FIG. 2.
  • FIG. 2 is a cross-sectional diagram showing an example DWC apparatus 150 with underreamer cutting pistons in the retracted configuration, according to aspects of the present disclosure. This view of the DWC apparatus 150 is along the A-A' sectional line of FIG. 1.
  • the DWC apparatus 250 comprises the drill bit 100 at one end.
  • the drill bit 100 is coupled to a bit shank 209 that includes a plurality of flow tubes 231 configured to transfer a drilling fluid (e.g., mud) to the drill bit through nozzles (not shown) in the drill bit 100.
  • the bit shank 209 further includes a passage 270 through which the fluid may transit the bit shank 209 to the drill bit 100.
  • the bit shank 209 couples the drill bit 100 to an underreamer 204 and may be adjusted to connect different size drill bits 100 to the underreamer 204.
  • the underreamer 204 includes cutting pistons 200-202 (also see FIG. 3).
  • the underreamer 204 is permanently connected to the end of the casing 203, as discussed subsequently, such that the DWC apparatus is non-retrievable after a drilling operation.
  • the underreamer 204 may include one or more of the cutting pistons 200-202 having cutting surfaces configured to enlarge the diameter of the borehole beyond the diameter of the DWC apparatus 150 with the underreamer cutting pistons 200-202 in the retracted position.
  • the cross-sectional diagram of FIG. 2 shows only one underreamer cutting piston 200.
  • FIG. 3 and the subsequent discussion illustrates that the present examples may include a plurality of underreamer cutting pistons 200- 202 disposed circumferentially around the underreamer 204. There are also no limitations as to the location or orientation of the underreamer cutting pistons 200-202 on the underreamer 204.
  • the underreamer cutting pistons 200-202 are each coupled to a respective pad 260 located within the underreamer 204. For purposes of clarity, only one pad 260 is shown. However, each of the underreamer cutting pistons 200-202 is coupled to its own respective pad 260. The one illustrated pad 260 is representative of each of the plurality of pads 260. Each pad 260 is configured to extend its respective underreamer cutting piston from the retracted position in response to being subjected to a fluid pressure.
  • Each pad 260 may be coupled to the underreamer 204 by one or more springs 240, 241.
  • the springs 240, 241 cause the respective pads 260 to be spring-loaded with respect to the underreamer 204 such that, after a fluid pressure that causes the underreamer cutting pistons 200- 202 to extend is removed, the springs are configured to retract the pads 260 with their respective underreamer cutting pistons 200-202 back to the retracted position.
  • the underreamer 204 may further include a passage 250.
  • the underreamer passage 250 may be coupled to the bit shank passage 270 to provide a substantially continuous passage from the casing 203, through the underreamer 204, bit shank 209, and nozzles 231 to the drill bit 100.
  • the substantially continuous passage 203, 250, 270, 231 enables the fluid (e.g., mud) to flow through the attached casing 203 , through the underreamer 204 and bit shank 209 to the drill bit 100.
  • the fluid may be used to cool the drill bit 100 during drilling operations.
  • the pressure of the fluid in the passage 250 exerts a pressure on the underreamer cutting piston pads 260.
  • the underreamer cutter pistons 200-202 may be activated when the internal fluid pressure is greater than an external pressure on the cutter pistons 200-202.
  • the pumping pressure used to activate the cutter pistons 200-202 may be changed by adjusting the internal diameter of the passage 250.
  • the underreamer cutter pistons 200-202 may be retained by shear pins 290 to keep the underreamer cutter pistons 200-202, and their respective pads 260, held within the underreamer 204 (e.g., retracted position) until the internal fluid pressure is equal to or greater than a
  • predetermined fluid pressure that is great enough to cause the shear pins to break.
  • FIG. 3 is a diagram showing an end view of an example DWC apparatus 150 with underreamer cutting pistons 200-202 in an extended configuration, according to aspects of the present disclosure.
  • This view shows one example orientation of the underreamer cutting pistons 200-202 extending out (e.g., extended position) from the underreamer 204.
  • the end view shows that the underreamer cutting pistons 200-202 may be substantially equally spaced (i.e., located at approximately 120° intervals) circumferentially around the underreamer 204. Other examples may locate the underreamer cutting pistons 200-202 in different locations.
  • the internal fluid pressure has increased beyond an external pressure or a pressure threshold set by the shear pins.
  • the fluid pressure causes the pads 260 with their respective underreamer cutting pistons 200-202 to extend into the extended position as shown in FIGs. 3 and 4.
  • FIG. 3 also shows section line B-B' that bisects the end of the apparatus 150.
  • the cross-sectional view of the apparatus 150 along this section line is illustrated in FIG. 4.
  • FIG. 4 is a cross-sectional diagram showing an example DWC apparatus 150 with underreamer cutting pistons 200-202 in the extended configuration, according to aspects of the present disclosure. This view of the DWC apparatus 150 is along the B-B' sectional line of FIG. 1.
  • the extended position is variable in response to fluid pressure.
  • the amount of extension of the underreamer pistons 200-202 may be controlled by controlling the fluid pressure: greater pressure extends the underreamer cutting pistons 200-202 further while lower pressure extends the underreamer cutting pistons 200-202 to a lesser extent.
  • the springs force provided by springs cause the underreamer cutting pistons 200-202 to retract into the underreamer 204, to the retracted position illustrated in FIGs. 1 and 2.
  • the initial internal fluid pressure that is greater than the external pressure or serves to break the shear pins may cause the
  • underreamer cutting pistons 200-202 to extend to one extended position. Once in that position, the underreamer cutting pistons 200-202 may be locked in that extended position.
  • FIG. 5 is a flowchart of an example method for a DWC operation, according to aspects of the present disclosure.
  • the casing attached to the DWC apparatus 150 is rotated. This causes the drill bit 100 of the DWC apparatus 150 to rotate and drill through a geological formation.
  • a fluid e.g., mud
  • the fluid travels through the casing 203, cutter piston 204, bit shank 209, and drill bit 100.
  • the fluid pressure may be increased to move the underreamer cutting pistons 200-202 from the retracted position to one or more extended positions in order to enlarge the diameter of the wellbore.
  • the fluid pressure increase beyond the predetermined fluid pressure used to break the shear pins causes the underreamer cutting pistons 200-202 to extend to the one or more extended positions.
  • the extended position may be variable (i.e., determined by the amount of pressure) or the extended position may be one fixed position.
  • completion of the DWC operation includes refraining from removing the DWC apparatus 150.
  • the DWC apparatus 150 remains downhole and permanently connected to the casing (i.e., it is non-retrievable) during the hydrocarbon recovery operation. This may result in a savings of the time that might otherwise be used to retrieve the apparatus 150.
  • FIG. 6 is a diagram showing an example drilling system 664, according to aspects of the present disclosure.
  • a drilling rig 602 is disposed over a well 606 on the surface 604 of a subsurface formation 614 and may provide support for the DWC apparatus 150.
  • the DWC apparatus 150 may operate to penetrate the rotary table 610 for drilling the borehole 612 through the subsurface formations 614.
  • the DWC apparatus 150 with its attached casing may be rotated by the rotary table 610.
  • the DWC apparatus 150 may also be rotated by a motor (e.g., a mud motor) that is located down hole.
  • a motor e.g., a mud motor
  • a mud pump 632 may pump drilling fluid (sometimes known by those of ordinary skill in the art as "drilling mud") from a mud pit 634 through a hose 636, into the casing 618, and down to the drill bit 100 of the DWC apparatus 150.
  • the drilling fluid can flow out from the drill bit 100 and be returned to the surface 604 through an annular area 640 between the casing 618 and the sides of the borehole 612.
  • the drilling fluid may then be returned to the mud pit 634, where such fluid is filtered.
  • the drilling fluid may be used to cool the drill bit 100, as well as to provide lubrication for the drill bit 100 during drilling operations. Additionally, the drilling fluid may be used to remove subsurface formation cuttings created by operating the drill bit 100.
  • the workstation 654 and the controller 696 may include modules comprising hardware circuitry, a processor, and/or memory circuits that may store software program modules and objects, and/or firmware, and combinations thereof.
  • the workstation 654 and controller 696 may be configured to control the direction, depth, and diameter of the wellbore drilling by executing instructions in order to control the fluid pressure pumped downhole.
  • An example workstation 654 and controller 696 may be realized by the system of FIG. 7.
  • FIG. 7 is a block diagram of an example system 700 operable to execute the methods herein, according to aspects of the present disclosure.
  • the system 700 may include circuitry (e.g., a controller or workstation) 720, a memory 730, a communications unit 735, and a display unit 760 coupled together over a bus 737.
  • circuitry e.g., a controller or workstation
  • the circuitry 720 may be realized as a processor or a group of processors that may operate independently depending on an assigned function.
  • the circuitry 720 may include control circuitry such as one or more
  • the memory 730 may include volatile and/or non-volatile memory.
  • the memory may include read only memory (ROM), random access memory (RAM) (e.g., SRAM, DRAM), flash, optical drives, and/or magnetic disk storage (e.g., hard drives).
  • the communications unit 735 may include downhole communications for appropriately located sensors in a wellbore. Such downhole communications can include a telemetry system.
  • the communications unit 735 may use combinations of wired communication technologies and wireless technologies at frequencies that do not interfere with on-going measurements.
  • the bus 737 may provide electrical conductivity among the components of the system 700.
  • the bus 737 may include an address bus, a data bus, and a control bus, each independently configured or in an integrated format.
  • the bus 737 may be realized using a number of different communication mediums that allows for the distribution of components of the system 700.
  • the bus 737 can include a network. Use of the bus 737 can be regulated by the circuitry 720.
  • the system 700 may be arranged to control operation of the DWC apparatus 150 and execute steps to perform the method of FIG. 5.
  • the system 700 may control the direction of the DWC apparatus 150 as well as the fluid pressure to the DWC apparatus 150 in order to control the position of the underreamer cutting pistons 200-202.
  • the interface unit(s) 760 may allow a user to interface, control, and/or monitor the operation of the DWC apparatus 150 or components distributed within the system 700.
  • the display units 760 may take the form of monitors, key boards, and/or touchscreen displays. Many embodiments may thus be realized, and the elements of several will now be listed in detail.
  • Example 1 is a drilling with casing apparatus comprising: a drill bit having a built-in casing connection; and an underreamer coupled to a casing and connected to the casing connection, the underreamer including underreamer cutting pistons having a retracted position and an extended position, wherein the underreamer is permanently connected to the casing.
  • Example 2 the subject matter of Example 1 can optionally include wherein the extended position comprises a variable extended position in response to a fluid pressure applied to the underreamer.
  • Example 3 the subject matter of Examples 1 -2 can optionally include wherein the underreamer further comprises a plurality of pads within the underreamer, each pad coupled to a respective underreamer cutting piston and configured to extend its respective underreamer cutting piston from the retracted position in response to a fluid pressure that is equal to or greater than a predetermined fluid pressure.
  • Example 4 the subject matter of Examples 1-3 can optionally include a shear pin coupled to each underreamer cutter piston wherein the shear pin is configured to break at the predetermined fluid pressure.
  • Example 5 the subject matter of Examples 1 -4 can optionally include wherein each of the plurality of pads is coupled to the underreamer with a spring making the pad spring-loaded with respect to the underreamer such that, after the fluid pressure is removed, the springs are configured to retract the pads with their respective underreamer cutting piston back to the retracted position.
  • Example 6 the subject matter of Examples 1-5 can optionally include wherein the extended position is a fixed extended position.
  • Example 7 the subject matter of Examples 1-6 can optionally include a bit shank configured to couple the drill bit to the underreamer.
  • Example 8 the subject matter of Examples 1-7 can optionally include wherein the underreamer further comprises a passage coupled between the casing and a passage of the bit shank such that a fluid from the casing flows through the underreamer and bit shank to the drill bit.
  • Example 9 the subject matter of Examples 1-8 can optionally include wherein the underreamer cutting pistons are disposed circumferentially around the underreamer.
  • Example 10 the subject matter of Examples 1-9 can optionally include wherein the underreamer cutting pistons in the extended position are configured to enlarge a diameter of a borehole beyond a diameter of the apparatus with the underreamer cutting pistons in the retracted position.
  • Example 11 is a method for performing a drilling operation with a drilling with casing apparatus, the method comprising: rotating the apparatus in a geological formation; pumping a fluid down a casing included in the apparatus and through a underreamer, the underreamer comprising extendable underreamer cutting pistons; increasing a pressure of the fluid to cause the underreamer cutting pistons to move from a retracted position to an extended position; and refraining from removing the apparatus after the drilling operation.
  • Example 12 the subject matter of Example 11 can optionally include wherein increasing the pressure of the fluid to cause the underreamer cutting pistons to move from a retracted position to an extended position moves the underreamer cutting pistons to a fixed extended position.
  • Example 13 the subject matter of Examples 11-12 can optionally include wherein increasing the pressure of the fluid to cause the underreamer cutting pistons to move from a retracted position to an extended position moves the underreamer cutting pistons to a variable extended position.
  • Example 14 the subject matter of Examples 11-13 can optionally include wherein the variable extended position is determined in response to the pressure of the fluid.
  • Example 15 the subject matter of Examples 11-14 can optionally include wherein increasing the pressure of the fluid comprises increasing the pressure of the fluid beyond a predetermined pressure that breaks shear pins holding the underreamer cutting pistons in the retracted position.
  • Example 16 the subject matter of Examples 11-15 can optionally include wherein refraining from removing the apparatus comprises leaving the apparatus connected to a casing.
  • Example 17 is a system comprising: a drilling rig disposed on a surface of a geological formation; and a drilling with casing apparatus supported by the drilling rig, the drilling with casing apparatus comprising: a drill bit having a built-in casing connection; and an underreamer coupled to a casing and connected to the casing connection, the underreamer including expandable underreamer cutting pistons, wherein the underreamer is permanently connected to the casing such that the apparatus is configured to be non-retrievable after a drilling with casing operation.
  • Example 18 the subject matter of Example 17 can optionally include wherein the expandable underreamer cutting pistons comprise a plurality of cutting pistons having a retracted position and an extended position selectable by a fluid pressure applied within the underreamer.
  • Example 19 the subject matter of Examples 17-18 can optionally include wherein the plurality of cutting pistons are substantially equally spaced circumferentially around the underreamer.
  • Example 20 the subject matter of Examples 17-19 can optionally include wherein the plurality of cutting pistons are configured to be retractable from the extended position.
  • Example 21 the subject matter of Examples 17-20 can optionally include wherein the casing connection comprises a casing thread having a casing taper that cannot connect to a drill pipe.

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  • Engineering & Computer Science (AREA)
  • Life Sciences & Earth Sciences (AREA)
  • Geology (AREA)
  • Mining & Mineral Resources (AREA)
  • Physics & Mathematics (AREA)
  • Environmental & Geological Engineering (AREA)
  • Fluid Mechanics (AREA)
  • General Life Sciences & Earth Sciences (AREA)
  • Geochemistry & Mineralogy (AREA)
  • Mechanical Engineering (AREA)
  • Earth Drilling (AREA)

Abstract

Dans certains modes de réalisation, un forage avec un appareil de tubage comprend un trépan de forage jetable couplé à un élargisseur. L'élargisseur est couplé entre le trépan de forage et un tubage. L'élargisseur comprend des pistons de coupe d'élargisseur ayant une position rétractée et une position déployée. L'élargisseur est relié en permanence au tubage de telle sorte que l'appareil est configuré pour être non récupérable après une opération de forage.
PCT/US2015/020723 2015-03-16 2015-03-16 Forage avec un appareil de tubage, procédé et système WO2016148682A1 (fr)

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PCT/US2015/020723 WO2016148682A1 (fr) 2015-03-16 2015-03-16 Forage avec un appareil de tubage, procédé et système

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PCT/US2015/020723 WO2016148682A1 (fr) 2015-03-16 2015-03-16 Forage avec un appareil de tubage, procédé et système

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Cited By (1)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US11158442B2 (en) 2015-04-03 2021-10-26 Schlumberger Technology Corporation Manufacturing techniques for a jacketed metal line

Citations (5)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US20030164251A1 (en) * 2000-04-28 2003-09-04 Tulloch Rory Mccrae Expandable apparatus for drift and reaming borehole
US20090223717A1 (en) * 2008-03-04 2009-09-10 Pathfinder Energy Services, Inc. Forced balanced system
US20110220357A1 (en) * 2010-03-15 2011-09-15 Richard Segura Section Mill and Method for Abandoning a Wellbore
US20130133949A1 (en) * 2008-05-05 2013-05-30 Weatherford/Lamb, Inc. Extendable cutting tools for use in a wellbore
US20140374170A1 (en) * 2013-06-19 2014-12-25 Toby Scott Baudoin Underreamer Apparatus and Method

Patent Citations (5)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US20030164251A1 (en) * 2000-04-28 2003-09-04 Tulloch Rory Mccrae Expandable apparatus for drift and reaming borehole
US20090223717A1 (en) * 2008-03-04 2009-09-10 Pathfinder Energy Services, Inc. Forced balanced system
US20130133949A1 (en) * 2008-05-05 2013-05-30 Weatherford/Lamb, Inc. Extendable cutting tools for use in a wellbore
US20110220357A1 (en) * 2010-03-15 2011-09-15 Richard Segura Section Mill and Method for Abandoning a Wellbore
US20140374170A1 (en) * 2013-06-19 2014-12-25 Toby Scott Baudoin Underreamer Apparatus and Method

Cited By (1)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US11158442B2 (en) 2015-04-03 2021-10-26 Schlumberger Technology Corporation Manufacturing techniques for a jacketed metal line

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