WO2014116934A1 - Hydraulic activation of mechanically operated bottom hole assembly tool - Google Patents
Hydraulic activation of mechanically operated bottom hole assembly tool Download PDFInfo
- Publication number
- WO2014116934A1 WO2014116934A1 PCT/US2014/012928 US2014012928W WO2014116934A1 WO 2014116934 A1 WO2014116934 A1 WO 2014116934A1 US 2014012928 W US2014012928 W US 2014012928W WO 2014116934 A1 WO2014116934 A1 WO 2014116934A1
- Authority
- WO
- WIPO (PCT)
- Prior art keywords
- drilling fluid
- flow
- drop balls
- hydraulic pressure
- bottom hole
- Prior art date
Links
- 230000004913 activation Effects 0.000 title claims description 24
- 239000012530 fluid Substances 0.000 claims abstract description 77
- 238000005553 drilling Methods 0.000 claims abstract description 72
- 238000000034 method Methods 0.000 claims abstract description 35
- 230000003213 activating effect Effects 0.000 claims abstract description 7
- 238000011144 upstream manufacturing Methods 0.000 claims description 13
- 239000006187 pill Substances 0.000 claims description 8
- 239000000463 material Substances 0.000 claims description 7
- 238000010008 shearing Methods 0.000 claims description 4
- 230000002401 inhibitory effect Effects 0.000 claims 5
- 238000010586 diagram Methods 0.000 description 11
- 238000005520 cutting process Methods 0.000 description 6
- 238000005086 pumping Methods 0.000 description 3
- 239000006260 foam Substances 0.000 description 2
- 239000007788 liquid Substances 0.000 description 2
- 239000003381 stabilizer Substances 0.000 description 2
- 244000043261 Hevea brasiliensis Species 0.000 description 1
- 239000000654 additive Substances 0.000 description 1
- 239000011324 bead Substances 0.000 description 1
- 230000015572 biosynthetic process Effects 0.000 description 1
- 239000004568 cement Substances 0.000 description 1
- 238000004140 cleaning Methods 0.000 description 1
- 230000007423 decrease Effects 0.000 description 1
- 229920001971 elastomer Polymers 0.000 description 1
- 238000004519 manufacturing process Methods 0.000 description 1
- 238000012986 modification Methods 0.000 description 1
- 230000004048 modification Effects 0.000 description 1
- 229920003052 natural elastomer Polymers 0.000 description 1
- 229920001194 natural rubber Polymers 0.000 description 1
- 239000004033 plastic Substances 0.000 description 1
- 239000007787 solid Substances 0.000 description 1
- 238000000638 solvent extraction Methods 0.000 description 1
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
- E21B7/00—Special methods or apparatus for drilling
- E21B7/28—Enlarging drilled holes, e.g. by counterboring
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B10/00—Drill bits
- E21B10/26—Drill bits with leading portion, i.e. drill bits with a pilot cutter; Drill bits for enlarging the borehole, e.g. reamers
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B10/00—Drill bits
- E21B10/60—Drill bits characterised by conduits or nozzles for drilling fluids
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B21/00—Methods or apparatus for flushing boreholes, e.g. by use of exhaust air from motor
- E21B21/10—Valve arrangements in drilling-fluid circulation systems
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B34/00—Valve arrangements for boreholes or wells
- E21B34/06—Valve arrangements for boreholes or wells in wells
- E21B34/063—Valve or closure with destructible element, e.g. frangible disc
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B34/00—Valve arrangements for boreholes or wells
- E21B34/06—Valve arrangements for boreholes or wells in wells
- E21B34/14—Valve arrangements for boreholes or wells in wells operated by movement of tools, e.g. sleeve valves operated by pistons or wire line tools
- E21B34/142—Valve arrangements for boreholes or wells in wells operated by movement of tools, e.g. sleeve valves operated by pistons or wire line tools unsupported or free-falling elements, e.g. balls, plugs, darts or pistons
-
- 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
- E21B2200/00—Special features related to earth drilling for obtaining oil, gas or water
- E21B2200/04—Ball valves
Definitions
- This specification generally relates to systems for and methods of hydraulic activation of a mechanically operated tool positionable in a bottom hole assembly used in drilling a wellbore.
- a drill string is lowered into a wellbore.
- the drill string is rotated.
- the rotation of the drill string provides rotation to a drill bit coupled to the distal end of a bottom hole assembly ("BHA") that is coupled to the distal end of the drill string.
- BHA bottom hole assembly
- the bottom hole assembly may include stabilizers, reamers, measurement-while-drilling ("MWD”) tools, logging-while-drilling (“LWD”) tools and other downhole equipment as known in the art.
- a downhole mud motor may be disposed in the bottom hole assembly above the drill bit to rotate the bit instead of rotating the drill string to provide rotation to the drill bit.
- FIG. 1 is a diagram of an example bottom hole assembly featuring a near-bit reamer.
- FIG. 2A is a side view of the lower end of the bottom hole assembly illustrating the near-bit reamer coupled to a drill bit.
- FIG. 2B is a cross-sectional side view of a portion of the near-bit reamer of FIG. 2A.
- FIGS. 3A-3C are cross-sectional perspective, top, and side views of a drill bit fitted with a grate actuation assembly.
- FIGS. 4A-4C are sequential diagrams of a technique for using deformable drop balls to activate a near-bit reamer.
- FIG. 5 is a flowchart illustrating a method of activating a near-bit reamer that involves creating a temporary flow restriction upstream of the near-bit reamer.
- FIG. 6 is a flowchart illustrating a method of activating a near-bit reamer that involves introducing a highly viscous pill fluid to the bottom hole assembly.
- FIG. 7 is a cross-sectional perspective view of a first example filter actuation assembly.
- FIGS. 7A-7B are sequential diagrams illustrating operation of the first example filter actuation assembly.
- FIG. 8A is an exploded diagram illustrating a second example of a filter actuation assembly.
- FIGS. 8B and 8C are perspective and cross-sectional side views of the second example filter actuation assembly in an assembled form.
- FIGS. 8D-8F are sequential diagrams illustrating operation of the second example filter actuation assembly.
- FIG. 9 is a cross-sectional perspective view of a third example of a filter actuation assembly.
- FIGS. 10A is a cross-sectional side view of a lower section of a bottom hole assembly featuring an activation bushing.
- FIG. 10B is a cross-sectional perspective view of the activation bushing of FIG 10A.
- FIGS. IOC and 10D are sequential diagrams illustrating operation of the activation bushing of FIGS. 10A and 10B.
- the present disclosure includes methods and devices for hydraulic activation of a mechanically operated bottom hole assembly tool.
- a near-bit borehole opener/enlargement tool also known as a near-bit reamer ("NBR")
- NBR near-bit reamer
- the present disclosure relates to devices that may be used to activate cutting blocks of a borehole opener tool by adjusting the hydraulic pressure of the drilling fluid within a bottom hole assembly.
- FIG. 1 is a diagram of an example bottom hole assembly 10.
- the bottom hole assembly 10 is the lower component of a drill string 12 suspended from a drilling rig (not shown).
- the upper end of the bottom hole assembly 10 includes a conventional under reaming tool 14 (e.g., a Halliburton model XR Reamer or UR-type conventional under reaming tool).
- a conventional under reaming tool 14 e.g., a Halliburton model XR Reamer or UR-type conventional under reaming tool.
- MWD measurement- while-drilling
- LWD logging- while-drilling
- the MWD/LWD tool string section 16 is positioned below the conventional under reaming tool 14 so that the enlarged borehole will not degrade performance of the MWD/LWD tools or the associated stabilizer elements 18.
- RSS rotary steerable system
- the RSS tool string 20 is located below the conventional under reaming tool 14 in order to ensure its proper functioning.
- the lower end of the bottom hole assembly 10 features an NBR 100 mounted just above the drill bit 22 and below the RSS tool string 20.
- FIG. 2 A is a side view of the lower end of the bottom hole assembly 10 illustrating the NBR 100 and the drill bit 22.
- the NBR 100 and the drill bit 22 are directly adjacent on the bottom hole assembly 10.
- the NBR 100 includes a plurality of cutting blocks 202 to engage to wall of the surrounding wellbore.
- the cutting blocks 202 are positioned circumferentially about an elongated body 204 of the NBR 100.
- the NBR 100 includes three cutting blocks 202 located at circumferential intervals of 120°.
- any suitable arrangement of cutting blocks may be used in various other embodiments and implementations without departing from the scope of the present disclosure.
- Each of the cutting blocks 202 includes a cutter element 206 disposed on a radial piston 208 disposed inside the elongated body 204.
- the cutter elements are initially in a radially-retracted position.
- the cutter elements 206 are moved radially outward relative to a central longitudinal axis 212 to contact the wellbore wall.
- the cutter elements 206 abrade and cut away the formation, thereby expanding the diameter of the borehole.
- FIG. 2B is a cross-sectional side view of the NBR 100.
- each of the radial pistons 208 includes an anchor plate 216.
- the radial pistons 208 are held in place by shear pins 218 such that the cutter elements 206 are in the radially -retracted position.
- the cutter elements 206 are deployed by hydraulic pressure. That is, when the hydraulic pressure in the body 204 reaches a predetermined threshold, the pressure force acts on the anchor plates 216 to urge the radial pistons 208 radially outward with sufficient force to break the shear pins 218.
- the radial pistons are moved by the hydraulic pressure of the drilling fluid outward toward the wall of the wellbore, deploying the cutter elements 206.
- the shear strength rating of the shear pins 218 determines the hydraulic pressure required to activate the NBR 100. In some examples, the shear pins 218 have shear strength rating of 120 bars, which corresponds to a hydraulic activation pressure for the NBR 100.
- the NBR 100 further includes biasing members 220 (e.g., disk or coil springs) mounted between the anchor plates 216 of the radial pistons 208 and an outer flange 222 secured to the body 204.
- biasing members 220 e.g., disk or coil springs mounted between the anchor plates 216 of the radial pistons 208 and an outer flange 222 secured to the body 204.
- the NBR 100 is activated by increasing hydraulic pressure of the drilling fluid beyond a predetermined threshold determined by the shear strength rating of the shear pins 218.
- the NBR may be activated by inserting one or more drop balls into a drilling fluid flow stream; pumping the drop balls in the drilling fluid down the drill string and into the bottom hole assembly; flowing the drilling fluid and drop balls through the NBR at a first hydraulic pressure; plugging one or more flow orifices (e.g., drill bit nozzles inlets or filter holes) thereby restricting flow of the drilling fluid upstream of the restriction and increasing the hydraulic pressure in the drilling fluid in the NBR upstream of the restriction to a predefined second hydraulic pressure.
- flow orifices e.g., drill bit nozzles inlets or filter holes
- the increased hydraulic pressure acting on a surface of the NBR creates a shearing force on a shear pin which shears when it reaches a predetermined sheer force and allows the NBR to be activated with the predefined second hydraulic pressure of the drilling fluid flowing through the NBR.
- FIGS. 3A-3C are cross-sectional perspective, top, and side views of a drill bit 22 fitted with a grate actuation assembly 300 designed to facilitate a drop-ball technique for increasing hydraulic pressure to activate the NBR 100.
- the drill bit 22 is a fixed cutter directional drill bit with multiple (in this case, seven) nozzle inlets 302 for ejecting drilling fluid.
- the NBR-activation techniques discussed in the present disclosure are applicable to other suitable drill bits as well.
- the grate actuation assembly 300 is located in a central fluid passage 304 defined by the shank 306 of the drill bit 22. The grate actuation assembly 300 abuts the base of the central fluid passage 304 to cover the nozzle inlets 302.
- the grate actuation assembly 300 includes a generally cylindrical body 308 having a sloped top surface 310 including a series of guide slots 312.
- the sloped surface 310 and the guide slots 312 are designed to direct one or more drop balls (not shown) towards an opening 314 proximal to the wall of the central fluid passage 304.
- the opening 314 provides access to the nozzle inlets 302 of the drill bit 22.
- the guide slots 312 are formed having a width less than the diameter of the drop balls. This configuration allows the drilling fluid to pass through the guide slots 312 to reach the nozzle inlets 302, while preventing the drop balls from passing through.
- a directional surface 316 leads the drop balls through the opening 314 and towards the nozzle inlets 302.
- the directional surface 316 slopes in a direction opposing the sloped top surface 310.
- Other suitable configurations and arrangements for leading the drop balls towards the drill bit nozzle inlets are also contemplated.
- the grate actuation assembly 300 further includes a gate structure 318 partitioning the area of the central fluid passage 304 near the nozzle inlets 302, creating a protected area 320. The gate structure 318 prevents the drop balls from entering the protected area 320 and encountering the nozzle inlets 302 within.
- the grate actuation assembly 300 is designed to facilitate plugging at least some of the nozzles 302 in a first unprotected area of the bit but not the nozzle inlets 302 in the second protected area 320.
- the increased hydraulic pressure acting on the assembly creates a shearing force on a shear pin which shears when it reaches a predetermined shear force and allows the NBR to be activated with the predefined second hydraulic pressure of the drilling fluid flowing through the NBR.
- This configuration allows the hydraulic pressure within the bottom hole assembly 10 to be increased by a sufficient amount to activate the NBR 100 without entirely preventing the ejection of drilling fluid from the bit.
- the magnitude of hydraulic pressure increase scales with the number of nozzle inlets 302 that are plugged by drop balls.
- the grate actuation assembly 300 can be designed to allow access by the one or more drop balls to a specific number of nozzle inlets 302, via positioning of the gate structure 318, in order to achieve a specific hydraulic pressure increase.
- FIGS. 4A-4C are sequential diagrams of a technique for using deformable drop balls 400 to activate the NBR 100.
- the deformable drop balls are formed from a flexible material (e.g., a material including rubber, foam, and/or plastic).
- one or more deformable drop balls 400 are pumped through the bottom hole assembly 10 toward the nozzle inlets of the drill bit 22.
- the deformable drop balls 400 encounter and plug the nozzle inlets to increase the hydraulic pressure within the bottom hole assembly 10 to a level sufficient to activate the NBR 100.
- the deformable drop balls 400 are eventually forced through the nozzle openings.
- the deformable drop balls 400 can be designed to shred under hydraulic pressure and pass through the nozzle openings in smaller pieces.
- the deformable drop balls 400 can be designed to deform and compress ("squeeze") through the nozzle openings under hydraulic pressure.
- the deformable drop balls 400 are designed to pass through the nozzle openings of the drill bit at a drilling fluid hydraulic pressure greater than what is required to activate the NBR 100.
- Controlling the hydraulic pressure increase within the bottom hole assembly 10 can be achieved by altering various process parameters (e.g., the number of deformable drop balls, the size of the deformable drop balls, the material properties of the deformable drop balls, etc.).
- the deformable drop balls 400 are Halliburton's Foam Wiper Balls, which are made of natural rubber of open cell design.
- the deformable drop balls are used to plug the nozzle inlets of the drill bit, but other configurations and arrangements are also contemplated.
- the deformable drop balls can be used to plug any orifice(s) downstream of the NBR 100.
- FIG. 5 is a flowchart illustrating a method 500 that involves temporarily creating an upstream flow restriction to generate a positive hydraulic pressure pulse sufficient to activate the NBR 100.
- a flow restriction is created upstream of the NBR 100.
- the flow restriction can be created, for example, using an activation technique for operating a different downhole assembly tool.
- the conventional under reaming tool 14 is activated using a drop-ball technique that creates the temporary upstream flow restriction.
- an electronically activated valve is at least partially closed to create the temporary upstream flow restriction.
- the hydraulic pressure pulse activates the NBR 100.
- the upstream flow restriction is relieved to reestablish the flow of drilling fluid.
- FIG. 6 is a flowchart illustrating yet another method 600 for creating a temporary pressuring increase sufficient to activate the NBR 100.
- the method 600 involves a highly viscous pill fluid.
- a general-purpose drilling fluid is pumped through the bottom hole assembly 10.
- a high- viscosity pill fluid is pumped through the bottom hole assembly 10 in place of the general-purpose drilling fluid. Pumping the high-viscosity pill fluid creates a hydraulic pressure increase within the bottom hole assembly 10 that is sufficient to activate the NBR 100.
- the pumping of the high-viscous pill fluid is ceased and the general-purpose drilling fluid is reestablished in the bottom hole assembly 10, restoring the original hydraulic pressure.
- the pill fluid is a high- viscosity liquid (e.g., mud gunk, such as Halliburton's Geltone), such as used for well cleaning operations.
- the pill fluid is a slurry-type fluid including liquid and small solid additives (e.g., Halliburton's fine Lubra-Beads or lost circulation material).
- a filter actuation assembly positioned upstream of the drill- bit nozzles and downstream of the NBR is used in conjunction with drop balls to generate a sufficient hydraulic pressure increase for activating the NBR 100.
- the filter actuation assembly can include a filter head supported by one or more shear pins.
- the filter head includes an array of flow orifices designed with a small diameter for plugging by the drop balls. Plugging the flow orifices on the filter head creates a flow restriction that causes a hydraulic pressure increase.
- hydraulic pressure reaches a certain level (which is greater than the NBR-activation hydraulic pressure)
- the pressure force bearing on the filter head causes the shear pins to break. Without the supporting shear pins, the filter head moves to a new position in the bottom hole assembly and opens a new flow path for the drilling fluid to pass, which relieves the hydraulic pressure buildup.
- FIG. 7 is a cross-sectional perspective view of a first example filter actuation assembly 700.
- the filter actuation assembly 700 includes a filter head 702, a set of axially oriented pillars 704 and a base plate 706.
- the filter head 702 is mounted on one or more secondary radial shear pins (see FIGS. 7A-7B).
- the filter head 702 defines an array of axial flow passages 708 aligned with the patterned flow openings 710 of the base plate 706.
- the diameter of the axial flow passages 708 is smaller than the diameter of the drop balls, so that drop balls encountering the filter head 702 effectively plug the flow passages.
- the axial flow passages 708 and flow openings 710 allow drilling fluid to pass through the filter actuation assembly 700.
- the flow passages 708 being plugged by drop balls 712, as shown in FIG. 7A, the flow of drilling fluid is restricted to the ancillary flow passages 714 at the radial edge of the filter head 702 and base plate 706 (see FIG. 7).
- the hydraulic pressure buildup eventually causes the shear pin 716 to break, allowing the filter head 702 to slide downward to rest against the base plate 706.
- the pillars 704 project through the axial flow passages 708 to displace the drop balls 712 (See FIG. 7B).
- FIG. 8A is an exploded diagram illustrating a second example filter actuation assembly 800.
- FIG. 8B and 8C are perspective and cross-sectional side views of the filter actuation assembly 800 in an assembled form.
- the filter actuation assembly 800 includes a disc-shaped filter head 802 defining an array of axial flow passages 804.
- the filter head 802 is supported in a hollow cylindrical rack 806.
- the rack 806 includes an annular seat 808 for receiving the filter head 802, three axially extending legs 810 that support the seat, and an annular base 812.
- a cylindrical sleeve 814 fits concentrically around the rack 806.
- the sleeve 814 includes an inner sheath 816 and an outer sheath 818.
- the inner sheath 816 defines an annular lip 820 that seals against the filter head 802 to prevent drilling fluid from leaking between the two filter-assembly components.
- the cylindrical side wall of the inner sheath 816 defines a plurality of axial slots 822.
- the sleeve 814 is held in place against the rack 806 by secondary shear pins 824 traversing radial openings 826 in the legs 810 of the rack and radial openings 828 in the outer sheath 818.
- FIGS. 8D-8F are sequential diagrams illustrating operation of the filter actuation assembly 800.
- FIG. 8D when the flow passages 804 (see FIGS 8A to 8C) of the filter head 802 are clear of any drop balls, drilling fluid flows downstream unimpeded through the filter head and the rack 806.
- FIG.8E when the drop balls 830 encounter the filter head 802, the flow passages 804(see FIGS 8A to 8C) become plugged, restricting the flow of drilling fluid through the bottom hole assembly 10 to build sufficient hydraulic pressure for activation of the NBR 100. As the hydraulic pressure continues to build, the pressure acting on the filter head 802 and rack 806 create as force until the shear pins 824 are severed upon reaching a predetermined shear force.
- FIG. 9 is a cross-sectional perspective view of a third example filter actuation assembly 900.
- the filter actuation assembly 900 includes a support member 902 mounted to the an interior wall of the bottom hole assembly 10, a filter head 904 coupled to the support member, and an axial flow orifice 906.
- the filter head 904 includes an array of radial flow openings 908 distributed along a frustoconical sidewall 910.
- drilling fluid flows freely through the filter head 904, passing through the radial flow openings 908 and the axial flow orifice 906.
- flow through the filter head 904 is severely inhibited, if not entirely prevented.
- the drilling fluid flow is restricted to an ancillary flow path formed by a gap 912 between the filter head 904 and the support member 902.
- the restriction of fluid flow achieved by plugging the filter head 904 creates a hydraulic pressure increase sufficient to activate the NBR 100.
- FIG. 1 OA is a cross-sectional side view of a lower section of the bottom hole assembly 10 featuring an activation bushing 1000.
- FIG. 10B is a cross-sectional perspective view of the activation bushing 1000.
- the activation bushing is installed at the interface between the shank 1002 of the drill bit 22 and the central bore of the NBR 100.
- the activation busing 1000 could be located at any position within the bottom hole assembly lOdownstream of the NBR 100.
- the activation bushing 1000 includes a flanged cylindrical base 1004 mounted and sealed against the wall of the central fluid passage 1006 in the drill bit 22.
- a slotted inlet structure 1008 aligns with a main flow passage 1010 extending through the base 1004 of the activation bushing 1000.
- Multiple ancillary flow passages 1012 are spaced circumferentially around the cylindrical base 1004.
- the slotted inlet structure 1008 is provided with a sloped, conical tip that prevents drop balls from plugging the main flow passage 1010.
- the ancillary flow passages 1012 on the other hand are oriented axially and designed to be plugged by the drop balls.
- FIGS. IOC and 10D are sequential diagrams illustrating operation of the activation bushing 1000.
- FIG. IOC when the ancillary flow passages 1012 are clear of any drop balls, drilling fluid flows unimpeded through the ancillary flow passages and the main flow passage 1010.
- FIG. 10D when the ancillary flow passages 1012 have been plugged by the drop balls 1014, the flow of drilling fluid is confined to the main flow passage 1010.
- the reduction in flow area achieved by plugging at least some of the ancillary flow passages 1012 creates a hydraulic pressure increase in the drilling fluid sufficient to activate the NBR 100.
Abstract
Description
Claims
Priority Applications (6)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
BR112015012129A BR112015012129A2 (en) | 2013-01-25 | 2014-01-24 | mechanically operated bottom composition tool hydraulics activation |
US14/369,901 US9121226B2 (en) | 2013-01-25 | 2014-01-24 | Hydraulic activation of mechanically operated bottom hole assembly tool |
CA2896652A CA2896652C (en) | 2013-01-25 | 2014-01-24 | Hydraulic activation of mechanically operated bottom hole assembly tool |
EP14743763.6A EP2948612A4 (en) | 2013-01-25 | 2014-01-24 | Hydraulic activation of mechanically operated bottom hole assembly tool |
CN201480003258.5A CN104854298B (en) | 2013-01-25 | 2014-01-24 | The hydraulic actuation of mechanically operated bottom hole assembly tool |
US14/808,608 US9810025B2 (en) | 2013-01-25 | 2015-07-24 | Hydraulic activation of mechanically operated bottom hole assembly tool |
Applications Claiming Priority (2)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
US201361756617P | 2013-01-25 | 2013-01-25 | |
US61/756,617 | 2013-01-25 |
Related Child Applications (2)
Application Number | Title | Priority Date | Filing Date |
---|---|---|---|
US14/369,901 A-371-Of-International US9121226B2 (en) | 2013-01-25 | 2014-01-24 | Hydraulic activation of mechanically operated bottom hole assembly tool |
US14/808,608 Continuation US9810025B2 (en) | 2013-01-25 | 2015-07-24 | Hydraulic activation of mechanically operated bottom hole assembly tool |
Publications (1)
Publication Number | Publication Date |
---|---|
WO2014116934A1 true WO2014116934A1 (en) | 2014-07-31 |
Family
ID=51228059
Family Applications (1)
Application Number | Title | Priority Date | Filing Date |
---|---|---|---|
PCT/US2014/012928 WO2014116934A1 (en) | 2013-01-25 | 2014-01-24 | Hydraulic activation of mechanically operated bottom hole assembly tool |
Country Status (6)
Country | Link |
---|---|
US (2) | US9121226B2 (en) |
EP (1) | EP2948612A4 (en) |
CN (1) | CN104854298B (en) |
BR (1) | BR112015012129A2 (en) |
CA (1) | CA2896652C (en) |
WO (1) | WO2014116934A1 (en) |
Cited By (2)
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WO2016108854A1 (en) * | 2014-12-30 | 2016-07-07 | Halliburton Energy Services, Inc. | Multi shot activation system |
EP2692982A3 (en) * | 2012-08-01 | 2017-07-26 | Halliburton Energy Services, Inc. | Near-bit borehole opener tool and method of reaming |
Families Citing this family (6)
Publication number | Priority date | Publication date | Assignee | Title |
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US10113394B2 (en) * | 2014-02-11 | 2018-10-30 | Smith International, Inc. | Multi-stage flow device |
WO2016168259A1 (en) * | 2015-04-15 | 2016-10-20 | M-I Drilling Fluids Uk Ltd. | Fish through filter device |
GB2553547B (en) | 2016-09-07 | 2019-12-04 | Ardyne Holdings Ltd | Downhole tool and method of use |
WO2019147820A1 (en) * | 2018-01-24 | 2019-08-01 | Stabil Drill Specialties, L.L.C. | Eccentric reaming tool |
US10794142B2 (en) * | 2018-05-02 | 2020-10-06 | Baker Hughes, A Ge Company, Llc | Plug seat with enhanced fluid distribution and system |
CN112096327A (en) * | 2020-10-10 | 2020-12-18 | 中国石油集团渤海钻探工程有限公司 | Reverse circulation throwing type drilling tool filter |
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Also Published As
Publication number | Publication date |
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US20150083497A1 (en) | 2015-03-26 |
EP2948612A1 (en) | 2015-12-02 |
BR112015012129A2 (en) | 2017-07-11 |
EP2948612A4 (en) | 2017-02-22 |
CN104854298A (en) | 2015-08-19 |
US9810025B2 (en) | 2017-11-07 |
US20150330182A1 (en) | 2015-11-19 |
CA2896652A1 (en) | 2014-07-31 |
CA2896652C (en) | 2018-06-05 |
CN104854298B (en) | 2017-06-23 |
US9121226B2 (en) | 2015-09-01 |
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