US20110232970A1 - Coiled tubing percussion drilling - Google Patents
Coiled tubing percussion drilling Download PDFInfo
- Publication number
- US20110232970A1 US20110232970A1 US13/052,245 US201113052245A US2011232970A1 US 20110232970 A1 US20110232970 A1 US 20110232970A1 US 201113052245 A US201113052245 A US 201113052245A US 2011232970 A1 US2011232970 A1 US 2011232970A1
- Authority
- US
- United States
- Prior art keywords
- impact tool
- coiled tubing
- drill bit
- actuating
- drilling
- 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.)
- Abandoned
Links
- 238000005553 drilling Methods 0.000 title claims abstract description 44
- 238000009527 percussion Methods 0.000 title description 9
- 238000000034 method Methods 0.000 claims abstract description 27
- IJGRMHOSHXDMSA-UHFFFAOYSA-N Atomic nitrogen Chemical compound N#N IJGRMHOSHXDMSA-UHFFFAOYSA-N 0.000 claims description 43
- 239000012530 fluid Substances 0.000 claims description 31
- 239000007789 gas Substances 0.000 claims description 18
- 229910052757 nitrogen Inorganic materials 0.000 claims description 16
- 230000004044 response Effects 0.000 claims description 14
- 238000005086 pumping Methods 0.000 claims description 10
- 230000035939 shock Effects 0.000 claims description 9
- 238000006073 displacement reaction Methods 0.000 claims description 8
- 239000006096 absorbing agent Substances 0.000 claims description 7
- 239000003638 chemical reducing agent Substances 0.000 claims description 7
- 239000000314 lubricant Substances 0.000 claims description 7
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims description 7
- 239000006260 foam Substances 0.000 claims description 6
- QVGXLLKOCUKJST-UHFFFAOYSA-N atomic oxygen Chemical compound [O] QVGXLLKOCUKJST-UHFFFAOYSA-N 0.000 claims description 4
- 239000003595 mist Substances 0.000 claims description 4
- 239000001301 oxygen Substances 0.000 claims description 4
- 229910052760 oxygen Inorganic materials 0.000 claims description 4
- 239000007788 liquid Substances 0.000 claims description 3
- VNWKTOKETHGBQD-UHFFFAOYSA-N methane Chemical compound C VNWKTOKETHGBQD-UHFFFAOYSA-N 0.000 description 21
- 239000003345 natural gas Substances 0.000 description 7
- 230000008901 benefit Effects 0.000 description 3
- 230000015572 biosynthetic process Effects 0.000 description 2
- 238000005755 formation reaction Methods 0.000 description 2
- 230000001788 irregular Effects 0.000 description 2
- 230000000737 periodic effect Effects 0.000 description 2
- 239000004094 surface-active agent Substances 0.000 description 2
- 238000007792 addition Methods 0.000 description 1
- 238000004891 communication Methods 0.000 description 1
- 230000007797 corrosion Effects 0.000 description 1
- 238000005260 corrosion Methods 0.000 description 1
- 238000012217 deletion Methods 0.000 description 1
- 230000037430 deletion Effects 0.000 description 1
- 238000005259 measurement Methods 0.000 description 1
- 239000012528 membrane Substances 0.000 description 1
- 230000000116 mitigating effect Effects 0.000 description 1
- 238000012986 modification Methods 0.000 description 1
- 230000004048 modification Effects 0.000 description 1
- 230000035515 penetration Effects 0.000 description 1
- 230000000750 progressive effect Effects 0.000 description 1
- 239000011435 rock Substances 0.000 description 1
- 238000000926 separation method Methods 0.000 description 1
- 238000006467 substitution reaction Methods 0.000 description 1
- 238000012546 transfer Methods 0.000 description 1
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
- E21B19/00—Handling rods, casings, tubes or the like outside the borehole, e.g. in the derrick; Apparatus for feeding the rods or cables
- E21B19/22—Handling reeled pipe or rod units, e.g. flexible drilling pipes
-
- 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
- E21B1/00—Percussion drilling
- E21B1/12—Percussion drilling with a reciprocating impulse member
- E21B1/24—Percussion drilling with a reciprocating impulse member the impulse member being a piston driven directly by fluid pressure
- E21B1/30—Percussion drilling with a reciprocating impulse member the impulse member being a piston driven directly by fluid pressure by air, steam or gas pressure
-
- 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
- E21B4/06—Down-hole impacting means, e.g. hammers
-
- 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
- E21B4/16—Plural down-hole drives, e.g. for combined percussion and rotary drilling; Drives for multi-bit drilling units
Definitions
- the present disclosure relates generally to equipment utilized and operations performed in conjunction with a subterranean well and, in an embodiment described herein, more particularly provides for coiled tubing percussion drilling.
- Percussion drilling has been used in the past in conjunction with segmented drill pipe, which has sufficient strength to absorb shocks produced by percussion drilling.
- Coiled tubing has been used in the past for drilling with a drill bit rotated by a positive displacement motor.
- FIG. 1 is a schematic partially cross-sectional view of a coiled tubing drilling system and method which embody principles of the present disclosure.
- FIG. 2 is a schematic elevational view of a bottom hole assembly which may be used in the system and method of FIG. 1 .
- FIG. 3 is a schematic elevational view of another configuration of the bottom hole assembly.
- FIG. 1 Representatively illustrated in FIG. 1 is a coiled tubing drilling system 10 and associated method which embody principles of the present disclosure.
- coiled tubing 12 is used to drill a wellbore 14 .
- the coiled tubing 12 is stored on a spool or reel 16 (e.g., by being wrapped about the reel).
- a tube guide 18 guides the coiled tubing 12 into an injector 20 , which is used to convey the coiled tubing into and out of the wellbore 14 .
- the coiled tubing 12 extends through a blowout preventer stack 22 connected to a wellhead 24 for pressure control. Although a land-based coiled tubing rig is depicted in FIG. 1 , coiled tubing can be deployed from floating rigs, jackups, platforms, subsea wellheads, or any other well location.
- Fluid communication with the interior of the coiled tubing 12 is provided via a conduit 26 secured to the reel 16 .
- fluids such as air 28 , water 30 , oil 32 , lubricant 34 , friction reducer 36 , natural gas 37 , mist 38 , foam 40 , surfactant 42 , nitrogen 44 , various gases 46 , drilling mud 47 , etc., or any combination thereof, may be flowed through the coiled tubing 12 during a drilling operation.
- Natural gas 37 is not currently preferred for use as the fluid, since relatively large amounts of this flammable gas would be needed to fill the coiled tubing 12 . Thus, the possible safety hazards may outweigh any economic benefits of using natural gas 37 .
- the nitrogen 44 may have any purity. For example, 95% purity nitrogen or 99.5 to 99.9% purity nitrogen may be used.
- the nitrogen 44 may be produced and/or delivered to a wellsite by any method.
- the nitrogen 44 may be produced on site (e.g., by a membrane separation process), or the nitrogen could be produced off site and delivered to the well location via piping or pressurized containers.
- the nitrogen 44 may be produced cryogenically.
- any gas 46 (such as nitrogen 44 ) used in the drilling operation is substantially free of oxygen, to thereby minimize corrosion of the coiled tubing 12 .
- a bottom hole assembly 48 is provided for performing various functions in the drilling operation.
- the main function performed by the bottom hole assembly 48 is cutting or drilling into the earth, in order to elongate the wellbore 14 .
- the bottom hole assembly 48 includes a drill bit 50 at its lower end.
- the drill bit 50 may be any type of drill bit, but is preferably designed specifically for percussion drilling (i.e., wherein impacts are repeatedly delivered to the drill bit for cutting into the earth).
- an impact tool 52 Connected above the drill bit 50 is an impact tool 52 which delivers the impacts to the drill bit.
- Various types of impact tools may be used (e.g., pneumatic, hydraulic, electrical, magnetic, etc.).
- the impacts may be delivered axially and/or torsionally to the drill bit 50 .
- An impact tool which may be used in the system 10 is the TORKBUSTERTM marketed by Ulterra of Fort Worth, Tex. USA. Impact tools are also described in U.S. Pat. Nos. 6,742,609, 6,659,202, 5,396,965 and 7,424,922, the entire disclosures of which are incorporated herein by this reference.
- the bottom hole assembly 48 can also include a variety of other components, such as measurement while drilling sensors, logging while drilling sensors, directional drilling equipment, weights, reamers, motors, shock absorbers, etc. A few of these are described more fully below, but it should be clearly understood that the bottom hole assembly 48 can comprise any number and combination of components, in keeping with the principles of this disclosure.
- the bottom hole assembly 48 includes a shock absorber 54 and one or more weights 56 (e.g., drill collars) connected to the coiled tubing 12 .
- weights 56 e.g., drill collars
- the impact tool depicted in FIG. 2 is a pneumatic hammer 52 a of the type which generates impacts in response to flow of gas 46 or other compressible fluids (such as air 28 , natural gas 37 , foam 40 , nitrogen 44 , etc., and/or combinations thereof).
- the pneumatic hammer 52 a may deliver the impacts to the drill bit 50 at regular periodic intervals, the impacts may be delivered at irregular intervals, or the impacts may be delivered only when desired, etc.
- the pneumatic hammer 52 a (or any other type of impact tool 52 ) could be combined with any of the other components of the bottom hole assembly 48 .
- the impact tool 52 could be combined with the drill bit 50 (e.g., as in the JACKBITTM marketed by NovaDrill of Provo, Utah USA), the shock absorber 54 and/or the weight 56 .
- the shock absorber 54 mitigates the transfer of shock and vibration from the impact tool 52 to the coiled tubing 12 . This aids in preventing fatigue damage to the coiled tubing 12 due to the operation of the impact tool 52 .
- the weight 56 aids the drilling operation by providing a downwardly biasing force to the drill bit 50 , and by providing an inertial mass against which the impact delivered by the impact tool 52 can react. The presence of this inertial mass also aids in mitigating fatigue damage to the coiled tubing 12 .
- the drill bit 50 may not rotate while the impacts are delivered from the impact tool 52 to the drill bit, and while the drill bit is cutting into the earth in the drilling operation.
- this example does not include any downhole means for rotating the drill bit 50 (although the impact tool 52 may cause rotation of the drill bit).
- other examples can incorporate rotation of the drill bit 50 into the drilling operation.
- FIG. 3 another configuration of the bottom hole assembly 48 is representatively illustrated.
- the drill bit 50 is rotated while the impacts are delivered by the impact tool 52 , and while the drill bit cuts into the earth.
- a positive displacement motor or drilling turbine 58 is interconnected in the bottom hole assembly 48 above the impact tool 52 .
- Positive displacement motors are also known to those skilled in the art as Moineau-type motors, progressive cavity motors and mud motors.
- Positive displacement motors and drilling turbines produce rotation in response to flow of fluid through the motors and turbines.
- Examples of positive displacement motors and drilling turbines are described in U.S. Pat. Nos. 6,742,609, 7,416,034, 6,883,622, 6,527,513, 7,500,787, 7,303,007 and 6,827,160, the entire disclosures of which are incorporated herein by this reference.
- a substantially incompressible fluid (or combination of fluids) is flowed through the motor or turbine 58 to rotate the drill bit 50 .
- the incompressible fluid(s) could be, for example, water 30 , oil 32 , lubricant 34 , friction reducer 36 and/or drilling mud 47 .
- the impact tool depicted in FIG. 3 is a fluid hammer 52 b of the type which generates impacts in response to flow of the incompressible fluid(s) through the fluid hammer.
- the fluid hammer 52 b may deliver the impacts to the drill bit 50 at regular periodic intervals, or the impacts may be delivered at irregular intervals, only when desired, etc.
- the flow of the incompressible fluid(s) can be used for operation of the fluid hammer 52 b , as well as for operation of the motor or turbine 58 .
- the above disclosure provides to the art a method of drilling a subterranean wellbore 14 .
- the method includes extending coiled tubing 12 into the wellbore 14 , and actuating an impact tool 52 interconnected to the coiled tubing 12 , thereby delivering impacts to a drill bit 50 .
- the impact tool 52 may comprise a fluid hammer 52 b or a pneumatic hammer 52 a.
- the method can include interconnecting a shock absorber 54 between the coiled tubing 12 and the impact tool 52 .
- Actuating the impact tool 52 may include pumping a liquid (such as water 30 , oil 32 , lubricant 34 , friction reducer 36 , surfactant 42 , drilling mud 47 , etc.) through the coiled tubing 12 to the impact tool 52 .
- a liquid such as water 30 , oil 32 , lubricant 34 , friction reducer 36 , surfactant 42 , drilling mud 47 , etc.
- Actuating the impact tool 52 may include pumping a gas 46 (such as air 28 , natural gas 37 , nitrogen 44 , etc.) through the coiled tubing 12 to the impact tool 52 .
- a gas 46 such as air 28 , natural gas 37 , nitrogen 44 , etc.
- the gas 46 may comprise nitrogen 44 .
- the gas 46 is substantially free of oxygen.
- Actuating the impact tool 52 can include pumping, along with the gas 46 , additional one or more components selected from a lubricant 34 , a friction reducer 36 , a foam 40 , oil 32 , mist 38 , drilling mud 47 , and water 30 .
- the method may include rotating the drill bit 50 while actuating the impact tool 52 .
- Rotating the drill bit 50 can include operating a positive displacement motor or turbine 58 which rotates the drill bit 50 in response to fluid flow through the coiled tubing 12 .
- Actuating the impact tool 52 may be performed while the drill bit 50 is not rotated.
- Actuating the impact tool 52 can include pumping a compressible fluid (such as air 28 , natural gas 37 , foam 40 , nitrogen 44 , other gases 46 , etc.) through the coiled tubing 12 to the impact tool 52 .
- a compressible fluid such as air 28 , natural gas 37 , foam 40 , nitrogen 44 , other gases 46 , etc.
- Actuating the impact tool 52 can include pumping an incompressible fluid (such as water 30 , oil 32 , lubricant 34 , friction reducer 36 , drilling mud 47 , etc.) through the coiled tubing 12 to the impact tool 52 .
- an incompressible fluid such as water 30 , oil 32 , lubricant 34 , friction reducer 36 , drilling mud 47 , etc.
- the system 10 can include coiled tubing 12 , a drill bit 50 , and an impact tool 52 which delivers impacts to the drill bit 50 .
Abstract
A method of drilling a subterranean wellbore can include extending coiled tubing into the wellbore, and actuating an impact tool interconnected to the coiled tubing, thereby delivering impacts to a drill bit. A coiled tubing drilling system for drilling a subterranean wellbore can include coiled tubing, a drill bit, and an impact tool which delivers impacts to the drill bit.
Description
- This application claims the benefit under 35 USC §119 of the filing date of International Application Serial No. PCT/US10/28570, filed Mar. 25, 2010. The entire disclosure of this prior application is incorporated herein by this reference.
- The present disclosure relates generally to equipment utilized and operations performed in conjunction with a subterranean well and, in an embodiment described herein, more particularly provides for coiled tubing percussion drilling.
- Percussion drilling has been used in the past in conjunction with segmented drill pipe, which has sufficient strength to absorb shocks produced by percussion drilling. Coiled tubing has been used in the past for drilling with a drill bit rotated by a positive displacement motor.
- However, certain benefits could be achieved if percussion drilling could be used in conjunction with coiled tubing. Therefore, it will be appreciated that improvements are needed in the arts of coiled tubing drilling and percussion drilling.
-
FIG. 1 is a schematic partially cross-sectional view of a coiled tubing drilling system and method which embody principles of the present disclosure. -
FIG. 2 is a schematic elevational view of a bottom hole assembly which may be used in the system and method ofFIG. 1 . -
FIG. 3 is a schematic elevational view of another configuration of the bottom hole assembly. - Representatively illustrated in
FIG. 1 is a coiledtubing drilling system 10 and associated method which embody principles of the present disclosure. In thesystem 10 and method, coiledtubing 12 is used to drill awellbore 14. - The coiled
tubing 12 is stored on a spool or reel 16 (e.g., by being wrapped about the reel). Atube guide 18 guides thecoiled tubing 12 into aninjector 20, which is used to convey the coiled tubing into and out of thewellbore 14. - The
coiled tubing 12 extends through ablowout preventer stack 22 connected to awellhead 24 for pressure control. Although a land-based coiled tubing rig is depicted inFIG. 1 , coiled tubing can be deployed from floating rigs, jackups, platforms, subsea wellheads, or any other well location. - Fluid communication with the interior of the coiled
tubing 12 is provided via aconduit 26 secured to thereel 16. In various examples described herein, fluids such as air 28, water 30, oil 32, lubricant 34, friction reducer 36, natural gas 37, mist 38, foam 40, surfactant 42, nitrogen 44, various gases 46, drilling mud 47, etc., or any combination thereof, may be flowed through the coiledtubing 12 during a drilling operation. - Natural gas 37 is not currently preferred for use as the fluid, since relatively large amounts of this flammable gas would be needed to fill the coiled
tubing 12. Thus, the possible safety hazards may outweigh any economic benefits of using natural gas 37. - The nitrogen 44 may have any purity. For example, 95% purity nitrogen or 99.5 to 99.9% purity nitrogen may be used. The nitrogen 44 may be produced and/or delivered to a wellsite by any method.
- The nitrogen 44 may be produced on site (e.g., by a membrane separation process), or the nitrogen could be produced off site and delivered to the well location via piping or pressurized containers. The nitrogen 44 may be produced cryogenically. Preferably, any gas 46 (such as nitrogen 44) used in the drilling operation is substantially free of oxygen, to thereby minimize corrosion of the
coiled tubing 12. - At a lower end of the coiled
tubing 12, abottom hole assembly 48 is provided for performing various functions in the drilling operation. Of course, the main function performed by thebottom hole assembly 48 is cutting or drilling into the earth, in order to elongate thewellbore 14. - For this purpose, the
bottom hole assembly 48 includes adrill bit 50 at its lower end. Thedrill bit 50 may be any type of drill bit, but is preferably designed specifically for percussion drilling (i.e., wherein impacts are repeatedly delivered to the drill bit for cutting into the earth). - Connected above the
drill bit 50 is animpact tool 52 which delivers the impacts to the drill bit. Various types of impact tools may be used (e.g., pneumatic, hydraulic, electrical, magnetic, etc.). - The impacts may be delivered axially and/or torsionally to the
drill bit 50. An impact tool which may be used in thesystem 10 is the TORKBUSTER™ marketed by Ulterra of Fort Worth, Tex. USA. Impact tools are also described in U.S. Pat. Nos. 6,742,609, 6,659,202, 5,396,965 and 7,424,922, the entire disclosures of which are incorporated herein by this reference. - The
bottom hole assembly 48 can also include a variety of other components, such as measurement while drilling sensors, logging while drilling sensors, directional drilling equipment, weights, reamers, motors, shock absorbers, etc. A few of these are described more fully below, but it should be clearly understood that thebottom hole assembly 48 can comprise any number and combination of components, in keeping with the principles of this disclosure. - Referring additionally now to
FIG. 2 , an example of a configuration of thebottom hole assembly 48, apart from the remainder of thesystem 10, is schematically illustrated. In this example, thebottom hole assembly 48 includes a shock absorber 54 and one or more weights 56 (e.g., drill collars) connected to thecoiled tubing 12. - The impact tool depicted in
FIG. 2 is apneumatic hammer 52 a of the type which generates impacts in response to flow of gas 46 or other compressible fluids (such as air 28, natural gas 37, foam 40, nitrogen 44, etc., and/or combinations thereof). Thepneumatic hammer 52 a may deliver the impacts to thedrill bit 50 at regular periodic intervals, the impacts may be delivered at irregular intervals, or the impacts may be delivered only when desired, etc. - Note that, in other examples, the
pneumatic hammer 52 a (or any other type of impact tool 52) could be combined with any of the other components of thebottom hole assembly 48. For example, theimpact tool 52 could be combined with the drill bit 50 (e.g., as in the JACKBIT™ marketed by NovaDrill of Provo, Utah USA), the shock absorber 54 and/or theweight 56. - The shock absorber 54 mitigates the transfer of shock and vibration from the
impact tool 52 to thecoiled tubing 12. This aids in preventing fatigue damage to the coiledtubing 12 due to the operation of theimpact tool 52. - The
weight 56 aids the drilling operation by providing a downwardly biasing force to thedrill bit 50, and by providing an inertial mass against which the impact delivered by theimpact tool 52 can react. The presence of this inertial mass also aids in mitigating fatigue damage to thecoiled tubing 12. - In the configuration of
FIG. 2 , thedrill bit 50 may not rotate while the impacts are delivered from theimpact tool 52 to the drill bit, and while the drill bit is cutting into the earth in the drilling operation. Thus, this example does not include any downhole means for rotating the drill bit 50 (although theimpact tool 52 may cause rotation of the drill bit). However, other examples can incorporate rotation of thedrill bit 50 into the drilling operation. - Referring additionally now to
FIG. 3 , another configuration of thebottom hole assembly 48 is representatively illustrated. In this configuration, thedrill bit 50 is rotated while the impacts are delivered by theimpact tool 52, and while the drill bit cuts into the earth. - As depicted in
FIG. 3 , a positive displacement motor ordrilling turbine 58 is interconnected in thebottom hole assembly 48 above theimpact tool 52. Positive displacement motors are also known to those skilled in the art as Moineau-type motors, progressive cavity motors and mud motors. - Positive displacement motors and drilling turbines produce rotation in response to flow of fluid through the motors and turbines. Examples of positive displacement motors and drilling turbines are described in U.S. Pat. Nos. 6,742,609, 7,416,034, 6,883,622, 6,527,513, 7,500,787, 7,303,007 and 6,827,160, the entire disclosures of which are incorporated herein by this reference.
- Preferably, a substantially incompressible fluid (or combination of fluids) is flowed through the motor or
turbine 58 to rotate thedrill bit 50. The incompressible fluid(s) could be, for example, water 30, oil 32, lubricant 34, friction reducer 36 and/or drilling mud 47. - The impact tool depicted in
FIG. 3 is afluid hammer 52 b of the type which generates impacts in response to flow of the incompressible fluid(s) through the fluid hammer. Thefluid hammer 52 b may deliver the impacts to thedrill bit 50 at regular periodic intervals, or the impacts may be delivered at irregular intervals, only when desired, etc. - Thus, the flow of the incompressible fluid(s) can be used for operation of the
fluid hammer 52 b, as well as for operation of the motor orturbine 58. However, it should be clearly understood that it is not necessary for an impact tool used in combination with the motor orturbine 58 to generate impacts in response to flow of incompressible fluid, since other types of impact tools (such as those which generate impacts electrically, magnetically, etc.) could be used, in keeping with the principles of this disclosure. - It may now be fully appreciated that several advancements are provided to the arts of percussion drilling and coiled tubing drilling by the above disclosure. The
system 10 and method described above provide for an overall increased rate of penetration in the drilling operation (in part because connections typically do not need to be made in a coiled tubing string as a wellbore is being drilled, and percussion drilling is highly effective in harder rock formations), fluid-sensitive formations can be drilled using air 28, natural gas 37, nitrogen 44, other gases 46, etc., with the configuration ofFIG. 2 , whereas substantially incompressible fluids can be used with the configuration ofFIG. 3 . - In particular, the above disclosure provides to the art a method of drilling a
subterranean wellbore 14. The method includes extending coiledtubing 12 into thewellbore 14, and actuating animpact tool 52 interconnected to the coiledtubing 12, thereby delivering impacts to adrill bit 50. - The
impact tool 52 may comprise afluid hammer 52 b or apneumatic hammer 52 a. - The method can include interconnecting a
shock absorber 54 between thecoiled tubing 12 and theimpact tool 52. - Actuating the
impact tool 52 may include pumping a liquid (such as water 30, oil 32, lubricant 34, friction reducer 36, surfactant 42, drilling mud 47, etc.) through the coiledtubing 12 to theimpact tool 52. - Actuating the
impact tool 52 may include pumping a gas 46 (such as air 28, natural gas 37, nitrogen 44, etc.) through the coiledtubing 12 to theimpact tool 52. - The gas 46 may comprise nitrogen 44. Preferably, the gas 46 is substantially free of oxygen.
- Actuating the
impact tool 52 can include pumping, along with the gas 46, additional one or more components selected from a lubricant 34, a friction reducer 36, a foam 40, oil 32, mist 38, drilling mud 47, and water 30. - The method may include rotating the
drill bit 50 while actuating theimpact tool 52. Rotating thedrill bit 50 can include operating a positive displacement motor orturbine 58 which rotates thedrill bit 50 in response to fluid flow through the coiledtubing 12. - Actuating the
impact tool 52 may be performed while thedrill bit 50 is not rotated. - Actuating the
impact tool 52 can include pumping a compressible fluid (such as air 28, natural gas 37, foam 40, nitrogen 44, other gases 46, etc.) through the coiledtubing 12 to theimpact tool 52. - Actuating the
impact tool 52 can include pumping an incompressible fluid (such as water 30, oil 32, lubricant 34, friction reducer 36, drilling mud 47, etc.) through the coiledtubing 12 to theimpact tool 52. - Also described by the above disclosure is a coiled
tubing drilling system 10 for drilling asubterranean wellbore 14. Thesystem 10 can include coiledtubing 12, adrill bit 50, and animpact tool 52 which delivers impacts to thedrill bit 50. - It is to be understood that the various embodiments of the present disclosure described herein may be utilized in various orientations, such as inclined, inverted, horizontal, vertical, etc., and in various configurations, without departing from the principles of the present disclosure. The embodiments are described merely as examples of useful applications of the principles of the disclosure, which is not limited to any specific details of these embodiments.
- In the above description of the representative embodiments of the disclosure, directional terms, such as “above,” “below,” “upper,” “lower,” etc., are used for convenience in referring to the accompanying drawings. In general, “above,” “upper,” “upward” and similar terms refer to a direction toward the earth's surface along a wellbore, and “below,” “lower,” “downward” and similar terms refer to a direction away from the earth's surface along the wellbore.
- Of course, a person skilled in the art would, upon a careful consideration of the above description of representative embodiments of the disclosure, readily appreciate that many modifications, additions, substitutions, deletions, and other changes may be made to the specific embodiments, and such changes are contemplated by the principles of the present disclosure. Accordingly, the foregoing detailed description is to be clearly understood as being given by way of illustration and example only, the spirit and scope of the present invention being limited solely by the appended claims and their equivalents.
Claims (30)
1. A method of drilling a subterranean wellbore, the method comprising:
extending coiled tubing into the wellbore; and
actuating an impact tool interconnected to the coiled tubing, thereby delivering impacts to a drill bit.
2. The method of claim 1 , wherein the impact tool comprises a fluid hammer.
3. The method of claim 1 , wherein the impact tool comprises a pneumatic hammer.
4. The method of claim 1 , further comprising interconnecting a shock absorber between the coiled tubing and the impact tool.
5. The method of claim 1 , wherein actuating the impact tool further comprises pumping a liquid through the coiled tubing to the impact tool.
6. The method of claim 1 , wherein actuating the impact tool further comprises pumping a gas through the coiled tubing to the impact tool.
7. The method of claim 6 , wherein the gas comprises nitrogen.
8. The method of claim 6 , wherein the gas is substantially free of oxygen.
9. The method of claim 6 , wherein actuating the impact tool further comprises pumping, along with the gas, additional one or more components selected from a lubricant, a friction reducer, a foam, oil, a mist, drilling mud, and water.
10. The method of claim 1 , further comprising rotating the drill bit while actuating the impact tool.
11. The method of claim 10 , wherein rotating the drill bit further comprises operating a positive displacement motor which rotates the drill bit in response to fluid flow through the coiled tubing.
12. The method of claim 10 , wherein rotating the drill bit further comprises operating a turbine which rotates the drill bit in response to fluid flow through the coiled tubing.
13. The method of claim 1 , wherein actuating the impact tool is performed while the drill bit is not rotated by a motor.
14. The method of claim 1 , wherein actuating the impact tool further comprises pumping a compressible fluid through the coiled tubing to the impact tool.
15. The method of claim 1 , wherein actuating the impact tool further comprises pumping an incompressible fluid through the coiled tubing to the impact tool.
16. A coiled tubing drilling system for drilling a subterranean wellbore, the system comprising:
coiled tubing;
a drill bit; and
an impact tool which delivers impacts to the drill bit.
17. The system of claim 16 , wherein the drill bit rotates while the impact tool delivers the impacts to the drill bit.
18. The system of claim 16 , further comprising a positive displacement motor which rotates the drill bit in response to fluid flow through the coiled tubing.
19. The system of claim 16 , further comprising a turbine which rotates the drill bit in response to fluid flow through the coiled tubing.
20. The system of claim 16 , wherein the impact tool delivers the impacts to the drill bit while the drill bit is not rotated by a motor.
21. The system of claim 16 , wherein the impact tool actuates in response to a compressible fluid flowed through the coiled tubing to the impact tool.
22. The system of claim 16 , wherein the impact tool actuates in response to an incompressible fluid flowed through the coiled tubing to the impact tool.
23. The system of claim 16 , wherein the impact tool comprises a fluid hammer.
24. The system of claim 16 , wherein the impact tool comprises a pneumatic hammer.
25. The system of claim 16 , further comprising a shock absorber interconnected between the coiled tubing and the impact tool.
26. The system of claim 16 , wherein the impact tool actuates in response to a liquid flowed through the coiled tubing to the impact tool.
27. The system of claim 16 , wherein the impact tool actuates in response to a gas flowed through the coiled tubing to the impact tool.
28. The system of claim 27 , wherein the gas comprises nitrogen.
29. The system of claim 27 , wherein the gas is substantially free of oxygen.
30. The system of claim 27 , wherein the impact tool actuates in response to, along with the gas, additional one or more components selected from a lubricant, a friction reducer, a foam, oil, a mist, drilling mud, and water, flowed through the coiled tubing to the impact tool.
Priority Applications (1)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
US13/052,245 US20110232970A1 (en) | 2010-03-25 | 2011-03-21 | Coiled tubing percussion drilling |
Applications Claiming Priority (3)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
PCT/US2010/028570 WO2011119155A1 (en) | 2010-03-25 | 2010-03-25 | Coiled tubing percussion drilling |
USPCT/US10/28570 | 2010-03-25 | ||
US13/052,245 US20110232970A1 (en) | 2010-03-25 | 2011-03-21 | Coiled tubing percussion drilling |
Publications (1)
Publication Number | Publication Date |
---|---|
US20110232970A1 true US20110232970A1 (en) | 2011-09-29 |
Family
ID=44655071
Family Applications (1)
Application Number | Title | Priority Date | Filing Date |
---|---|---|---|
US13/052,245 Abandoned US20110232970A1 (en) | 2010-03-25 | 2011-03-21 | Coiled tubing percussion drilling |
Country Status (1)
Country | Link |
---|---|
US (1) | US20110232970A1 (en) |
Cited By (5)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US20120175106A1 (en) * | 2011-01-07 | 2012-07-12 | Rite Increaser, LLC | Drilling Fluid Diverting Sub |
US20130277116A1 (en) * | 2012-04-18 | 2013-10-24 | Ulterra Drilling Technologies, L.P. | Mud motor with integrated percussion tool and drill bit |
US20180274299A1 (en) * | 2015-01-08 | 2018-09-27 | Strada Design Limited | Multi fluid drilling system |
US10597945B2 (en) | 2016-02-12 | 2020-03-24 | Dover Chemical Corporation | Coiled-tubing fluid-lubricant composition and related methods |
CN111577177A (en) * | 2020-04-22 | 2020-08-25 | 中煤科工集团西安研究院有限公司 | Drilling device and drilling method for discharging slag by underground pneumatic impact crushed rock foam |
Citations (44)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US3946819A (en) * | 1975-01-27 | 1976-03-30 | Brown Equipment & Service Tools, Inc. | Well tool and method of use therefor |
US4144941A (en) * | 1977-09-30 | 1979-03-20 | Ritter Lester L | Directional impact tool for tunneling |
US4632191A (en) * | 1985-04-05 | 1986-12-30 | Gas Research Institute | Steering system for percussion boring tools |
US4694913A (en) * | 1986-05-16 | 1987-09-22 | Gas Research Institute | Guided earth boring tool |
US4862976A (en) * | 1988-11-22 | 1989-09-05 | Sandvik Rock Tools, Inc. | Spline drive for percussion drilling tool |
US4862958A (en) * | 1988-11-07 | 1989-09-05 | Camco, Incorporated | Coil tubing fluid power actuating tool |
US4867255A (en) * | 1988-05-20 | 1989-09-19 | Flowmole Corporation | Technique for steering a downhole hammer |
US4907658A (en) * | 1988-09-29 | 1990-03-13 | Gas Research Institute | Percussive mole boring device with electronic transmitter |
US5156223A (en) * | 1989-06-16 | 1992-10-20 | Hipp James E | Fluid operated vibratory jar with rotating bit |
US5396965A (en) * | 1989-01-23 | 1995-03-14 | Novatek | Down-hole mud actuated hammer |
US5421420A (en) * | 1994-06-07 | 1995-06-06 | Schlumberger Technology Corporation | Downhole weight-on-bit control for directional drilling |
US5449046A (en) * | 1993-12-23 | 1995-09-12 | Electric Power Research Institute, Inc. | Earth boring tool with continuous rotation impulsed steering |
US5602541A (en) * | 1991-05-15 | 1997-02-11 | Baroid Technology, Inc. | System for drilling deviated boreholes |
US6012536A (en) * | 1996-02-27 | 2000-01-11 | Tracto-Technik Schmidt Spezialmaschinen | Method for steering a ground-drilling machine |
US6109355A (en) * | 1998-07-23 | 2000-08-29 | Pes Limited | Tool string shock absorber |
US6253864B1 (en) * | 1998-08-10 | 2001-07-03 | David R. Hall | Percussive shearing drill bit |
US6315063B1 (en) * | 1999-11-02 | 2001-11-13 | Leo A. Martini | Reciprocating rotary drilling motor |
US6347675B1 (en) * | 1999-03-15 | 2002-02-19 | Tempress Technologies, Inc. | Coiled tubing drilling with supercritical carbon dioxide |
US6390207B2 (en) * | 1999-03-03 | 2002-05-21 | Earth Tool Company, L.L.C. | Method and apparatus for directional boring under mixed conditions |
US20020084109A1 (en) * | 2000-07-31 | 2002-07-04 | Randy Runquist | Steerable fluid hammer |
US20020088648A1 (en) * | 1997-01-30 | 2002-07-11 | Baker Hughes Incorporated | Drilling assembly with a steering device for coiled -tubing operations |
US20020166700A1 (en) * | 2001-05-11 | 2002-11-14 | Gillis Peter J. | Rotational impact drill assembly |
US20020185312A1 (en) * | 2001-05-03 | 2002-12-12 | Armell Richard A. | Impact tool |
US6527513B1 (en) * | 1998-07-31 | 2003-03-04 | Rotech Holdings Limited | Turbine for down-hole drilling |
US6533052B2 (en) * | 2001-01-03 | 2003-03-18 | Earth Tool Company, L.L.C. | Drill bit for impact-assisted directional boring |
US6536539B2 (en) * | 2000-06-30 | 2003-03-25 | S & S Trust | Shallow depth, coiled tubing horizontal drilling system |
US6554083B1 (en) * | 2001-12-05 | 2003-04-29 | Scott Kerstetter | Adjustable bent housing sub for a mud motor |
US6609577B2 (en) * | 2001-09-29 | 2003-08-26 | Bark International, Inc. | Percussive rotational impact hammer |
US6827160B2 (en) * | 2001-01-12 | 2004-12-07 | Hunting Performance, Inc. | Downhole mud motor |
US6883622B2 (en) * | 2000-07-21 | 2005-04-26 | Smith International, Inc. | Method for drilling a wellbore using a bi-center drill bit |
US6986394B2 (en) * | 2004-04-29 | 2006-01-17 | Varco I/P, Inc. | Reciprocable impact hammer |
US7073610B2 (en) * | 2001-05-19 | 2006-07-11 | Rotech Holdings Limited | Downhole tool |
US20070137897A1 (en) * | 2005-12-16 | 2007-06-21 | Sanders Michael P | Combined directional and impact drilling motor |
US7240744B1 (en) * | 2006-06-28 | 2007-07-10 | Jerome Kemick | Rotary and mud-powered percussive drill bit assembly and method |
US7303007B2 (en) * | 2005-10-07 | 2007-12-04 | Weatherford Canada Partnership | Method and apparatus for transmitting sensor response data and power through a mud motor |
US20080061621A1 (en) * | 2006-09-13 | 2008-03-13 | Sandvik Mining And Construction Lyon Sas | Flexible tubing for a rotary-percussion drilling device |
US7416034B2 (en) * | 2000-06-17 | 2008-08-26 | Smith International, Inc. | Drive system |
US7424922B2 (en) * | 2005-11-21 | 2008-09-16 | Hall David R | Rotary valve for a jack hammer |
US20090057018A1 (en) * | 2007-08-31 | 2009-03-05 | Precision Energy Services, Inc. | Directional drilling control using modulated bit rotation |
US7500787B2 (en) * | 2005-09-02 | 2009-03-10 | Nicu Cioceanu | Bearing assembly for downhole mud motor |
US20090194334A1 (en) * | 2007-08-15 | 2009-08-06 | Schlumberger Technology Corporation | System and method for drilling |
US20090260884A1 (en) * | 2008-04-16 | 2009-10-22 | Baker Hughes Incorporated | Steering Device for Downhole Tools |
US20100032209A1 (en) * | 2008-08-06 | 2010-02-11 | Atlas Copco Secoroc Llc | Percussion assisted rotary earth bit and method of operating the same |
US20100163308A1 (en) * | 2008-12-29 | 2010-07-01 | Precision Energy Services, Inc. | Directional drilling control using periodic perturbation of the drill bit |
-
2011
- 2011-03-21 US US13/052,245 patent/US20110232970A1/en not_active Abandoned
Patent Citations (47)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US3946819A (en) * | 1975-01-27 | 1976-03-30 | Brown Equipment & Service Tools, Inc. | Well tool and method of use therefor |
US4144941A (en) * | 1977-09-30 | 1979-03-20 | Ritter Lester L | Directional impact tool for tunneling |
US4632191A (en) * | 1985-04-05 | 1986-12-30 | Gas Research Institute | Steering system for percussion boring tools |
US4694913A (en) * | 1986-05-16 | 1987-09-22 | Gas Research Institute | Guided earth boring tool |
US4867255A (en) * | 1988-05-20 | 1989-09-19 | Flowmole Corporation | Technique for steering a downhole hammer |
US4907658A (en) * | 1988-09-29 | 1990-03-13 | Gas Research Institute | Percussive mole boring device with electronic transmitter |
US4862958A (en) * | 1988-11-07 | 1989-09-05 | Camco, Incorporated | Coil tubing fluid power actuating tool |
US4862976A (en) * | 1988-11-22 | 1989-09-05 | Sandvik Rock Tools, Inc. | Spline drive for percussion drilling tool |
US5396965A (en) * | 1989-01-23 | 1995-03-14 | Novatek | Down-hole mud actuated hammer |
US5156223A (en) * | 1989-06-16 | 1992-10-20 | Hipp James E | Fluid operated vibratory jar with rotating bit |
US5602541A (en) * | 1991-05-15 | 1997-02-11 | Baroid Technology, Inc. | System for drilling deviated boreholes |
US5449046A (en) * | 1993-12-23 | 1995-09-12 | Electric Power Research Institute, Inc. | Earth boring tool with continuous rotation impulsed steering |
US5421420A (en) * | 1994-06-07 | 1995-06-06 | Schlumberger Technology Corporation | Downhole weight-on-bit control for directional drilling |
US6012536A (en) * | 1996-02-27 | 2000-01-11 | Tracto-Technik Schmidt Spezialmaschinen | Method for steering a ground-drilling machine |
US20020088648A1 (en) * | 1997-01-30 | 2002-07-11 | Baker Hughes Incorporated | Drilling assembly with a steering device for coiled -tubing operations |
US6109355A (en) * | 1998-07-23 | 2000-08-29 | Pes Limited | Tool string shock absorber |
US6527513B1 (en) * | 1998-07-31 | 2003-03-04 | Rotech Holdings Limited | Turbine for down-hole drilling |
US6253864B1 (en) * | 1998-08-10 | 2001-07-03 | David R. Hall | Percussive shearing drill bit |
US6390207B2 (en) * | 1999-03-03 | 2002-05-21 | Earth Tool Company, L.L.C. | Method and apparatus for directional boring under mixed conditions |
US20030024739A1 (en) * | 1999-03-03 | 2003-02-06 | Vermeer Manufacturing Company | Method and apparatus for directional boring under mixed conditions |
US6347675B1 (en) * | 1999-03-15 | 2002-02-19 | Tempress Technologies, Inc. | Coiled tubing drilling with supercritical carbon dioxide |
US6315063B1 (en) * | 1999-11-02 | 2001-11-13 | Leo A. Martini | Reciprocating rotary drilling motor |
US7416034B2 (en) * | 2000-06-17 | 2008-08-26 | Smith International, Inc. | Drive system |
US6536539B2 (en) * | 2000-06-30 | 2003-03-25 | S & S Trust | Shallow depth, coiled tubing horizontal drilling system |
US6883622B2 (en) * | 2000-07-21 | 2005-04-26 | Smith International, Inc. | Method for drilling a wellbore using a bi-center drill bit |
US6659202B2 (en) * | 2000-07-31 | 2003-12-09 | Vermeer Manufacturing Company | Steerable fluid hammer |
US20020084109A1 (en) * | 2000-07-31 | 2002-07-04 | Randy Runquist | Steerable fluid hammer |
US6533052B2 (en) * | 2001-01-03 | 2003-03-18 | Earth Tool Company, L.L.C. | Drill bit for impact-assisted directional boring |
US6827160B2 (en) * | 2001-01-12 | 2004-12-07 | Hunting Performance, Inc. | Downhole mud motor |
US20020185312A1 (en) * | 2001-05-03 | 2002-12-12 | Armell Richard A. | Impact tool |
US20020166700A1 (en) * | 2001-05-11 | 2002-11-14 | Gillis Peter J. | Rotational impact drill assembly |
US6742609B2 (en) * | 2001-05-11 | 2004-06-01 | United Diamond Ltd. | Rotational impact drill assembly |
US7073610B2 (en) * | 2001-05-19 | 2006-07-11 | Rotech Holdings Limited | Downhole tool |
US6609577B2 (en) * | 2001-09-29 | 2003-08-26 | Bark International, Inc. | Percussive rotational impact hammer |
US6554083B1 (en) * | 2001-12-05 | 2003-04-29 | Scott Kerstetter | Adjustable bent housing sub for a mud motor |
US6986394B2 (en) * | 2004-04-29 | 2006-01-17 | Varco I/P, Inc. | Reciprocable impact hammer |
US7500787B2 (en) * | 2005-09-02 | 2009-03-10 | Nicu Cioceanu | Bearing assembly for downhole mud motor |
US7303007B2 (en) * | 2005-10-07 | 2007-12-04 | Weatherford Canada Partnership | Method and apparatus for transmitting sensor response data and power through a mud motor |
US7424922B2 (en) * | 2005-11-21 | 2008-09-16 | Hall David R | Rotary valve for a jack hammer |
US20070137897A1 (en) * | 2005-12-16 | 2007-06-21 | Sanders Michael P | Combined directional and impact drilling motor |
US7240744B1 (en) * | 2006-06-28 | 2007-07-10 | Jerome Kemick | Rotary and mud-powered percussive drill bit assembly and method |
US20080061621A1 (en) * | 2006-09-13 | 2008-03-13 | Sandvik Mining And Construction Lyon Sas | Flexible tubing for a rotary-percussion drilling device |
US20090194334A1 (en) * | 2007-08-15 | 2009-08-06 | Schlumberger Technology Corporation | System and method for drilling |
US20090057018A1 (en) * | 2007-08-31 | 2009-03-05 | Precision Energy Services, Inc. | Directional drilling control using modulated bit rotation |
US20090260884A1 (en) * | 2008-04-16 | 2009-10-22 | Baker Hughes Incorporated | Steering Device for Downhole Tools |
US20100032209A1 (en) * | 2008-08-06 | 2010-02-11 | Atlas Copco Secoroc Llc | Percussion assisted rotary earth bit and method of operating the same |
US20100163308A1 (en) * | 2008-12-29 | 2010-07-01 | Precision Energy Services, Inc. | Directional drilling control using periodic perturbation of the drill bit |
Cited By (9)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US20120175106A1 (en) * | 2011-01-07 | 2012-07-12 | Rite Increaser, LLC | Drilling Fluid Diverting Sub |
US9249639B2 (en) * | 2011-01-07 | 2016-02-02 | Rite Increaser, LLC | Drilling fluid diverting sub |
US20130277116A1 (en) * | 2012-04-18 | 2013-10-24 | Ulterra Drilling Technologies, L.P. | Mud motor with integrated percussion tool and drill bit |
US8851204B2 (en) * | 2012-04-18 | 2014-10-07 | Ulterra Drilling Technologies, L.P. | Mud motor with integrated percussion tool and drill bit |
US20180274299A1 (en) * | 2015-01-08 | 2018-09-27 | Strada Design Limited | Multi fluid drilling system |
US10544625B2 (en) * | 2015-01-08 | 2020-01-28 | Strada Design Limited | Multi fluid drilling system |
AU2016206187B2 (en) * | 2015-01-08 | 2020-05-14 | Strada Design Limited | Multi fluid drilling system |
US10597945B2 (en) | 2016-02-12 | 2020-03-24 | Dover Chemical Corporation | Coiled-tubing fluid-lubricant composition and related methods |
CN111577177A (en) * | 2020-04-22 | 2020-08-25 | 中煤科工集团西安研究院有限公司 | Drilling device and drilling method for discharging slag by underground pneumatic impact crushed rock foam |
Similar Documents
Publication | Publication Date | Title |
---|---|---|
US7481280B2 (en) | Method and apparatus for conducting earth borehole operations using coiled casing | |
Lyons | Air and gas drilling manual: applications for oil and gas recovery wells and geothermal fluids recovery wells | |
US7204327B2 (en) | Reverse circulation directional and horizontal drilling using concentric drill string | |
US8360160B2 (en) | Deep water drilling with casing | |
US7637316B2 (en) | Wellbore system | |
NO309994B1 (en) | Method and apparatus for placing a guide wedge | |
US10508495B2 (en) | Linear and vibrational impact generating combination tool with adjustable eccentric drive | |
US6412574B1 (en) | Method of forming a subsea borehole from a drilling vessel in a body of water of known depth | |
EP2569504B1 (en) | System and method for conducting drilling and coring operations | |
Patel et al. | A review on casing while drilling technology for oil and gas production with well control model and economical analysis | |
US20110232970A1 (en) | Coiled tubing percussion drilling | |
US20130037272A1 (en) | Method and system for well access to subterranean formations | |
US20120097452A1 (en) | Downhole Tool Deployment Measurement Method and Apparatus | |
US9970235B2 (en) | Rotary steerable drilling system for drilling a borehole in an earth formation | |
Nguyen | Drilling | |
Kerunwa et al. | OVERVIEW OF THE ADVANCES IN CASING DRILLING TECHNOLOGY. | |
US9284781B2 (en) | Oil and gas enhancement system—radial drilling method | |
NO20131133A1 (en) | Lateral wellbore apparatus and method | |
WO2011119155A1 (en) | Coiled tubing percussion drilling | |
Tercan | Managed pressure drilling techniques, equipment & applications | |
CN105745391A (en) | Compensator clip ring retainer cap for a roller cone drill bit | |
US20210324695A1 (en) | Multi-function mandrel system | |
Tejo et al. | A Unique Completion Design Using Perforated Drill Pipe in the Onshore Southern Sumatra Basin | |
Dyson | Well Engineering | |
Takase et al. | Successful Hole Enlargement Operations Utilizing Reaming While Drilling Techniques and Combining LWD operations in a Deep Water Drilling Environment |
Legal Events
Date | Code | Title | Description |
---|---|---|---|
AS | Assignment |
Owner name: HALLIBURTON ENERGY SERVICES, INC., TEXAS Free format text: ASSIGNMENT OF ASSIGNORS INTEREST;ASSIGNORS:MILLER, AARON M.;LEWIS, DERRICK W.;SIGNING DATES FROM 20110121 TO 20110309;REEL/FRAME:025988/0155 |
|
STCB | Information on status: application discontinuation |
Free format text: ABANDONED -- FAILURE TO RESPOND TO AN OFFICE ACTION |