WO2010028244A2 - Apparatus and system to allow tool passage ahead of a bit - Google Patents
Apparatus and system to allow tool passage ahead of a bit Download PDFInfo
- Publication number
- WO2010028244A2 WO2010028244A2 PCT/US2009/056039 US2009056039W WO2010028244A2 WO 2010028244 A2 WO2010028244 A2 WO 2010028244A2 US 2009056039 W US2009056039 W US 2009056039W WO 2010028244 A2 WO2010028244 A2 WO 2010028244A2
- Authority
- WO
- WIPO (PCT)
- Prior art keywords
- shaft
- drill bit
- running tool
- housing
- latch assembly
- Prior art date
Links
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
- E21B10/00—Drill bits
- E21B10/62—Drill bits characterised by parts, e.g. cutting elements, which are detachable or adjustable
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B23/00—Apparatus for displacing, setting, locking, releasing, or removing tools, packers or the like in the boreholes or wells
- E21B23/02—Apparatus for displacing, setting, locking, releasing, or removing tools, packers or the like in the boreholes or wells for locking the tools or the like in landing nipples or in recesses between adjacent sections of tubing
Definitions
- the invention relates generally to the field of drilling wellbores through subterranean formations. More specifically, the invention relates to devices capable of inserting instruments through drill bits used to perform certain operations in subterranean formations below the drill bit. Description of the Related Art
- a drill bit for such non-drilling operations would be undesirable because, for example, attempting to pump a fluid of high density or viscosity and/or comprising coarse material through the drill string with a drill bit attached has been found to be detrimental.
- conventional drill bits such as polycrystalline diamond cutter (PDC) bits or roller cone bits are provided with bit nozzles for discharging fluid from within a drill string into the wellbore.
- PDC polycrystalline diamond cutter
- Nozzles normally comprise a nozzle channel with a nozzle insert, and the orifice could in principle be increased by removing the nozzle inserts from the bit. This option is however not seriously contemplated in practice because it would significantly impair the performance of the bit for progressing into the formation.
- Other operations such as setting a cement plug may simply not be possible with a drill bit and may require other tools.
- the drill bit is typically removed from the drill string and is replaced by a suitable tool to perform non-drilling operations.
- a suitable tool for example, when injecting fluids, a tool is used with a sufficiently large orifice in order that fluid can be introduced. This most often means that the drill string is pulled from the borehole. Before pulling the drill string out of the borehole, it is often necessary to first temporarily stabilize the borehole by introducing lost circulation material. This stabilization may often be accomplished through ports in the lower part if the drill string above the drill bit that can be opened and closed again, for example in a circulating sub.
- Well logging devices include one or more sensors for measuring one or more physical parameters of the formations outside the wellbore and/or various parameters of the wellbore itself such as geodetic trajectory.
- the sensors are disposed in a housing configured to move along the interior of the wellbore.
- it is difficult to insert well logging instruments into portions of the wellbore due to, for example, high inclination of the wellbore from vertical or rough surface of the wellbore wall. In such cases it is desirable to dispose the drill string within such portions to provide a conduit or passage for the well logging instrument.
- the instrument may be exposed to the open wellbore by opening a passage in the drill bit, such as by removing a releasable insert, and moving the instrument through the opening.
- Previous devices to address the needs described above include providing a drill bit insert in the drill bit which is held in place by means of a ball-latch mechanism, detaching the drill bit insert through the use of a tool inserted into the drill string which is configured to unlatch the ball-latch mechanism, and deploying the tool through the opening in the drill bit created by removing the insert from the bit body. After completion of the task, the tool is then retracted and drill bit insert reattached to the drill bit by means of re-latching the ball-latch mechanism.
- the foregoing drill bit with an insert does not include the use of a latch mechanism in a sealed enclosure. Drilling mud and other fluids are capable of reaching the latch mechanism in such a situation and rendering it inoperable or causing the mechanism to spontaneously unlatch. Further, in the foregoing drill bits with inserts, the tool used to disengage the latching mechanism does not lock into the latching mechanism, allowing incomplete or misaligned attempts at unlatching the latching mechanism, or worse, release of the insert from the drill bit without its positive connection to the release tool. In such cases, the insert could fall to the bottom of the well, resulting in a difficult and expensive operation to retrieve the insert.
- a drill bit in one aspect of the invention includes a drill bit body defining an opening enabling longitudinal passage of an instrument therethrough, a drill bit insert disposed in the opening and a latch assembly coupled to the insert and configured to releasably retain the insert in the opening.
- the latch assembly is configured to operate only upon locking engagement therewith of a running tool, and the latch assembly is disposed in a substantially sealed enclosure.
- a running tool in another aspect of the invention is configured to operate a latch assembly only upon locking engagement therewith.
- the running tool includes a running tool housing with a circumference and a longitudinal axis, a drive shaft extending along longitudinal axis of the running tool and having an outer circumference, and a mating assembly enclosed within the running tool housing and configured to lockably engage the latch assembly.
- the running tool further includes a shaft trigger assembly, wherein the shaft trigger assembly is enclosed within the running tool housing and the shaft trigger assembly is configured to substantially prevent rotational movement of the drive shaft and a torsion spring.
- the torsion spring is mechanically connected to the drive shaft and configured to motivate the drive shaft to rotate.
- FIG. IA shows schematically a drill bit in accordance with one example of the present invention.
- FIG. IB shows an exploded view of a latch assembly in one example of the present invention.
- FIG. IC shows schematically a drill bit in accordance with one example of the present invention.
- FIG. 2 shows an exploded view of the trigger assembly of one example of the present invention.
- FIG. 3 shows a cross-sectional view of the latch assembly in the latched position in one example of the present invention.
- FIG. 4 shows a cross-sectional view of the latch assembly in the latched position in one example of the present invention.
- FIG. 5 shows a cross-sectional view of the latch assembly in the unlatched position in one example of the present invention.
- FIG. 6 shows a cross-sectional view of the latch assembly in the unlatched position in one example of the present invention.
- FIG. 7 shows an exploded view of the running tool in accordance with one example of the present invention.
- the invention enables the use of tools in a wellbore when it is undesirable or impossible to remove the drill bit.
- Examples of devices used in a wellbore when it is undesirable or impossible to remove the drill bit are disclosed in United States Patent No. 7,287,609, filed November 13, 2003, entitled “Drilling a Borehole,” and U.S. Patent No. 7,281,592, filed July 23, 2002, entitled “Injecting a Fluid into a Borehole Ahead of the Bit.”
- the term “upper” refers to a position or orientation relatively closer to the surface end of the drill string and the term “lower” is used to mean a position relatively closer to the subsurface end of the borehole during operation.
- FIG. IA shows schematically a longitudinal cross-section of a rotary drill bit consistent with the present invention.
- Drill bit (200) is shown in borehole (202) and is attached to lower end of a pipe or conduit, which may be a drill string (203), at the upper end of bit body (206).
- Drill bit insert (2) is disposed in bit body opening (212).
- Bit body (206) of drill bit (200) includes central longitudinal passageway (208) which allows fluid communication and passage of a tool between the interior of the drill string (203 a) through latch fluid passageway (214) of drill bit insert (2) to borehole (202) exterior to drill bit (200).
- Drill bit insert (2) is shown with cutting elements (216), although cutting elements are not required to be included on the insert (2). Also depicted are nozzles (3), although other examples of the insert (2) may exclude nozzles.
- bit body (206) further includes bit body groove (210) disposed at an upper end of the passageway (208). Bit body groove (210) is configured to releasably retain collet latch (24) as described below.
- FIG. IB is an exploded view of the latch assembly (1). As described further below, latch assembly (1) is configured to enable releasable coupling of the insert (2) to the bit body (206) to allow passage of a particular tool, such as a cementing tool, well logging tool or survey tool, through drill string (203) and into borehole (202).
- a particular tool such as a cementing tool, well logging tool or survey tool
- Latch assembly (1) is mechanically connected (for example, by threads) to drill bit insert (2) to allow retention of the insert (2) in the bit body (206 in FIG. IA) until it is to be released therefrom, and includes seal elements (4), cam (11) and collet assembly (22). Seal elements (4) act to substantially prevent fluids within the interior of the drill string, such as drilling mud, from entering latch assembly (1) through any gaps that may exist between drill bit insert (2) and cam (11). Seal elements (4) are depicted in FIGS. 1, 3, and 4 as including lower 0-ring (5), shim (6), rotary seal (7), and upper 0-ring (8).
- Inner circumferential surface (10) of lower 0-ring (5) is configured to circumferentially engage the outside circumferential surface (9) of bit insert (2). Shim (6) and rotary seal (7) are disposed between bit insert (2) and cam (11). Upper 0-ring (8) is disposed about the circumference of cam (11) as shown in FIGS. 4, 5, 6, and 7. Lower 0-ring (5) and upper 0-ring (8) may be composed of any suitable material. One non-limiting example of a suitable material is Buna-N rubber. As one of ordinary skill in the art will appreciate, the makeup of seal elements (4) is non-limiting and other seal element configurations are within the scope of the present invention. [0028] As shown in FIGS. 3, 4, 5, and 6, cam (11) seats against drill bit insert (2).
- Cam (11) includes cam body (14) and cam ring (16).
- Cam body (14) is shown here as generally cylindrical.
- Cam body (14) includes cam shoulder (13) which circumferentially extends about the outer surface of cam body (14); cam shoulder (13) is configured to facilitate a seal in conjunction with upper 0-ring (8) between cam (11) and housing (60) as shown in FIGS. 3, 4, 5 and 6.
- Cam body (14) further includes cylindrical ledge (15), a raised section of cam body designed to engage collet assembly (22) as described below.
- Disposed about the exterior surface of cam body (14) are one or more generally helical slots (18).
- generally helical slots (18) are "J-slots", as shown in FIG. IB. Helical slots (18) shown in FIG.
- Collet assembly (22) includes collet ring (21) and collet keys (23). As shown in FIGS. 3, 4, 5, and 6, collet assembly (22) is configured so as to circumferentially engage cylindrical ledge (15), with the lower surface of collect ring (21) juxtaposed against cam shoulder (13) and the inner surface collet ring (21) engaging the outer surface of cylindrical ledge (15). Collet keys (23) extend from the upper surface of collet ring (21). As further shown in FIG. IB, each of the collet keys (23) includes collet latch (24).
- Cam (11) further includes cam ring (16).
- Cam ring (16) concentrically contained within the collet keys (23) of collet assembly (22) so that in the engaged position the collet keys (23) are extended to lock the latch assembly (1) within the drill bit.
- Cam ring (16) further includes cam latch pins (28).
- Cam latch pins (28) project through cam ring (16) and are disposed so as to engage helical slots (18) on cam body (14) when cam ring (16) is concentrically positioned within the collet assembly (22).
- FIG. IB further shows spring (30).
- Spring (30) is juxtaposed on the upper surface of cam ring (16) and biases cam ring (16) towards drill bit insert (2).
- spring (30) acts to bias cam latch pins in hook portion of the J-slot.
- Latch assembly (1) is positioned within housing (60).
- Housing (60) is generally cylindrical and is configured to protect latch assembly (1) from drilling mud and other wellbore fluids by forming a substantially sealed enclosure around latch assembly (1).
- Housing (60) is mechanically connected to bit insert (2), typically by threading housing (60) to bit insert (2), although one of ordinary skill in the art will understand alternative methods of mechanically connecting housing (60) to bit insert (2).
- housing (60) further includes one or more apertures (32).
- Apertures (32) are situated along the circumference wall of housing (60) and are configured such that collet latches (24) protrude through apertures (32) when latch assembly (1) is in the latched position.
- housing (60) further includes inner diameter groove (40).
- Inner diameter groove (40) extends circumferentially about the inner diameter of housing (60).
- alignment keys (34) are positioned within inner diameter groove (40) and are configured to properly align and rotationally fix running tool (100) to latch assembly (1), as further described below.
- Running tool (100) is shown in FIG. 7 and includes mating assembly (101), drive shaft (110), shaft trigger assembly (130), running tool housing (102), torsion spring (160).
- Running tool (100) is configured to traverse central longitudinal passageway (208).
- Running tool housing (102) is approximately cylindrical and encloses mating assembly (101), drive shaft (110), shaft trigger assembly (130) and torsion spring (160) and is configured to protect these elements from drilling mud and other fluids that may exist within central longitudinal passageway (208).
- Drive shaft (110) is aligned along the longitudinal axis of running tool housing (100) and circumferentially encompassed by running tool housing (102).
- Drive shaft (110) includes shaft (112) and shaft head (114).
- Shaft head (114) is mechanically connected to drive shaft (110) and is configured to rotate with rotation of shaft (112).
- Shaft head (114) includes shaft head splines (116).
- Mating assembly (101) is configured to lockably engage running tool (100) with latch assembly (1).
- Mating assembly (101) includes upper collet assembly (140), upper collet support ring (150), and collet body (148) with guide slots (149).
- Upper collet support ring (150) circumferentially encloses and is mechanically connected to drive shaft (110).
- Upper collet assembly (140) includes upper collet frame (142), a ring that is configured to circumferentially enclosing drive shaft (110) such that drive shaft (110) can rotate and pass longitudinally therethrough, and upper collet keys (144), which extend from the upper surface of upper collet frame (142).
- upper collet support ring (150) is configured so as to be capable of longitudinally passing through upper collet frame (142).
- Upper collet keys (144) are prevented from contacting the surface of drive shaft (110) by upper collet support ring (150) when drive shaft (110) passes longitudinally therethrough.
- Upper collet (140) is seated against a ledge in the collet body (148). The collet body is mated to the Shaft Trigger assembly (130) so that the collet (140), collet body (148) and Shaft Trigger assembly (130) are able to move axially as a single unit within the Running tool Housing (102).
- the collet (140) is configured so that it is held in engaged in the running tool housing (102) and as such restrains the Shaft Trigger assembly (130) and collet body (148) until such time as it is activated by engagement with the latch assembly (1) as described below. Rotational translation by upper collet (140) within running tool housing (102) is substantially prevented by mechanical contact between the outer diameter of upper collet frame (142) and the inner diameter of running tool housing (102).
- FIG. 7 further shows guide slots (149).
- Guide slots (149) extend approximately perpendicularly from the inner surface of the collet body (148) and are configured to mechanically engage alignment keys (34), thereby lockably engaging running tool (100) to latch assembly (1).
- alignment keys (34) are mechanically engaged
- running tool assembly (100) and latch assembly (1) are aligned and rotationally fixed.
- running tool (100) is lockably engaged to latch assembly (1)
- splines (19) and shaft head splines (39) are aligned to allow mechanical engagement. Splines (19) and shaft head splines (39) will not properly engage unless latch assembly (1) is lockably engaged to running tool (100) by mating assembly (101).
- Upper collet keys further include upper collet key latch mechanisms (146).
- Upper collet key latch mechanisms (146) are configured so as to mechanically engage inner diameter groove (40) of housing (60). When mechanically engaged, inner diameter groove
- FIGS. 2 and 7 show shaft trigger assembly (130).
- Shaft trigger assembly (130) includes shaft trigger housing (139), which is generally cylindrical and circumferentially encloses drive shaft (110), shaft release triggers (132), key anti-rotation spring (136) and shaft pins (118).
- Shaft trigger assembly (130) is configured to substantially prevent axial movement of shaft (110).
- Pivotally attached to the outer circumference of shaft trigger housing (139) is one or more shaft release triggers (132).
- Each shaft release trigger includes notch (134).
- Key anti-rotation spring (136) is configured to fit within notch (134) and hold shaft release triggers (132) in place within the shaft trigger housing (139) so that the release triggers (132) are locked into a groove in the drive shaft (110), substantially preventing the translation of shaft 110 with respect to the trigger housing (139).
- Shaft trigger assembly (130) includes one or more shaft trigger grooves (138).
- Trigger assembly pins (118) extend from the body of the trigger assembly (130) and locate the trigger assembly rotationally within the running tool housing (102). Shaft pins (118) are further configured to allow longitudinal movement of the trigger assembly (130) within the running tool housing (102). [0044] As shown in FIGS.
- one or more of the Shaft Release triggers (132) extend from the outer circumference of the trigger housing (139) and protrude into slots in the running tool housing (102) so that the shaft trigger assembly (130) can be allowed to move axially within the running tool housing (102).
- Shaft release triggers (132) are further configured so that upon longitudinal movement of the shaft trigger assembly (130), the shaft release triggers (132) will engage the running tool housing (102).
- torsion spring (160) is wound about shaft (112) in compression and is prevented from rotating while the shaft roller bearings (120) reside within the bearing housing slot (121). Torsion spring (160) is substantially prevented from rotating shaft (110) until the shafts move axially shaft release triggers have been engaged by the running tool housing (102) as described below.
- running tool (100) is translated along central longitudinal passageway (208).
- Running tool (100) is mated with latch assembly (1) as described above by mechanically engaging guide pins (148) and alignment keys (34).
- Trigger assembly (139) and drive shaft (110) are longitudinally translated through running tool (100).
- Shaft release triggers (132) traverse shaft trigger grooves to engage running tool housing (102).
- Shaft triggers (132) pivot to release drive shaft (110).
- Shaft head splines rotationally translate splines (19), causing cam body (14) to rotate.
- the rotation of cam body (14) causes cam latch pins (28) and cam ring (16) to translate along helical slots (18).
- the translation of the cam ring (16) causes it to disengage from the collet keys (23) allowing the keys (23) to retract, thereby disengaging collet latch (24) from the bit body (206).
- the combination of gravity and longitudinal pressure exerted by drive shaft (110) on cam (11) moves the latch assembly (1) to the unlatched position as shown in FIGS. 5 and 6. [0047]
- latch assembly (1) may be pushed longitudinally along borehole (202) by mechanical pressure applied by drive shaft (110).
- latch assembly (1) may be completely disengaged from bit body (206), allowing drive shaft head (114) to longitudinally traverse the interior of housing (60).
- latch assembly (1) with insert attached (2) may be moved out from the bit body (206) enabling passage of the running tool and any instrument coupled to the running tool to be moved into the wellbore through the passage in the bit body.
- the tool, instrument and/or the running tool will include a "no-go" or similar device having a size larger than the diameter of the passage (210) in the bit body so that the instrument will be suspended by the drill string in the open wellbore below the drill bit.
- the instrument may be moved along the interior of the wellbore, for example, by withdrawing the drill string from the wellbore.
Abstract
Description
Claims
Priority Applications (3)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
EP09812281.5A EP2340347A4 (en) | 2008-09-05 | 2009-09-04 | Apparatus and system to allow tool passage ahead of a bit |
AU2009289516A AU2009289516B2 (en) | 2008-09-05 | 2009-09-04 | Apparatus and system to allow tool passage ahead of a bit |
CA2735938A CA2735938C (en) | 2008-09-05 | 2009-09-04 | Apparatus and system to allow tool passage ahead of a bit |
Applications Claiming Priority (2)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
US12/204,937 US7841400B2 (en) | 2008-09-05 | 2008-09-05 | Apparatus and system to allow tool passage ahead of a bit |
US12/204,937 | 2008-09-05 |
Publications (2)
Publication Number | Publication Date |
---|---|
WO2010028244A2 true WO2010028244A2 (en) | 2010-03-11 |
WO2010028244A3 WO2010028244A3 (en) | 2010-04-29 |
Family
ID=41797878
Family Applications (1)
Application Number | Title | Priority Date | Filing Date |
---|---|---|---|
PCT/US2009/056039 WO2010028244A2 (en) | 2008-09-05 | 2009-09-04 | Apparatus and system to allow tool passage ahead of a bit |
Country Status (5)
Country | Link |
---|---|
US (1) | US7841400B2 (en) |
EP (1) | EP2340347A4 (en) |
AU (1) | AU2009289516B2 (en) |
CA (1) | CA2735938C (en) |
WO (1) | WO2010028244A2 (en) |
Families Citing this family (14)
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US9359847B2 (en) | 2007-03-03 | 2016-06-07 | Longyear Tm, Inc. | High productivity core drilling system |
CN101675205B (en) * | 2007-03-03 | 2013-12-25 | 朗耶商标有限公司 | High productivity core drilling system |
AU2008237984B2 (en) * | 2007-04-12 | 2011-11-03 | Schlumberger Holdings Limited | Drill bit assembly and method of performing an operation in a wellbore |
US7967085B2 (en) * | 2008-04-22 | 2011-06-28 | Longyear Tm, Inc. | Braking devices for use in drilling operations |
WO2009147072A2 (en) * | 2008-06-02 | 2009-12-10 | Shell Internationale Research Maatschappij B.V. | Drill bit and method for inserting, expanding, collapsing, and retrieving drill bit |
US8646548B2 (en) * | 2008-09-05 | 2014-02-11 | Thrubit, Llc | Apparatus and system to allow tool passage ahead of a bit |
US8485280B2 (en) * | 2009-10-07 | 2013-07-16 | Longyear Tm, Inc. | Core drilling tools with retractably lockable driven latch mechanisms |
US8869918B2 (en) * | 2009-10-07 | 2014-10-28 | Longyear Tm, Inc. | Core drilling tools with external fluid pathways |
US9399898B2 (en) | 2009-10-07 | 2016-07-26 | Longyear Tm, Inc. | Core drilling tools with retractably lockable driven latch mechanisms |
US8794355B2 (en) | 2009-10-07 | 2014-08-05 | Longyear Tm, Inc. | Driven latch mechanism |
US9528337B2 (en) | 2009-10-07 | 2016-12-27 | Longyear Tm, Inc. | Up-hole bushing and core barrel head assembly comprising same |
GB2533731B (en) | 2013-11-14 | 2020-08-05 | Halliburton Energy Services Inc | Method and apparatus for ranging to a nearby well from ahead of a drill bit |
WO2018010001A1 (en) | 2016-07-14 | 2018-01-18 | L.B. Foster Rail Technologies, Corp. | Rail port insert |
CN109723390A (en) * | 2018-12-27 | 2019-05-07 | 贵州航天凯山石油仪器有限公司 | A kind of downhole instrument structure of giving up |
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US2173677A (en) * | 1933-06-20 | 1939-09-19 | Brewster Company Inc | Core barrel |
US2153815A (en) * | 1937-07-27 | 1939-04-11 | Elliott Core Drilling Company | Fluid operated latching means for inner drill assemblies |
US2719363A (en) * | 1953-01-19 | 1955-10-04 | Montgomery Richard Franklin | Calipering method and apparatus |
US2829868A (en) * | 1953-08-14 | 1958-04-08 | Longyear E J Co | Wire line core barrel |
US2726848A (en) * | 1954-09-27 | 1955-12-13 | Montgomery | Logging sub |
US3117636A (en) * | 1960-06-08 | 1964-01-14 | John L Wilcox | Casing bit with a removable center |
US3127943A (en) * | 1962-03-05 | 1964-04-07 | Christensen Diamond Prod Co | Wire line core barrel |
US3169592A (en) * | 1962-10-22 | 1965-02-16 | Lamphere Jean K | Retrievable drill bit |
US3241624A (en) * | 1963-01-24 | 1966-03-22 | Central Mine Equipment Company | Earth boring equipment including two part rotary cutting head |
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US5472057A (en) * | 1994-04-11 | 1995-12-05 | Atlantic Richfield Company | Drilling with casing and retrievable bit-motor assembly |
US5568838A (en) * | 1994-09-23 | 1996-10-29 | Baker Hughes Incorporated | Bit-stabilized combination coring and drilling system |
FI96356C (en) * | 1994-12-13 | 1999-12-18 | Valto Ilomaeki | Drilling method and blade assembly to implement the method |
AUPN357995A0 (en) * | 1995-06-15 | 1995-07-06 | Rear, Ian Graeme | Down hole hammer assembly |
AUPN505395A0 (en) * | 1995-08-28 | 1995-09-21 | Down Hole Technologies Pty Ltd | Tool for transporting cutting means to and from a ground drill |
AUPN505295A0 (en) * | 1995-08-28 | 1995-09-21 | Down Hole Technologies Pty Ltd | Retraction system for a latching mechanism of the tool |
US6269891B1 (en) * | 1998-09-21 | 2001-08-07 | Shell Oil Company | Through-drill string conveyed logging system |
EP1366270B1 (en) * | 2001-03-09 | 2019-09-04 | Schlumberger Holdings Limited | Logging system for use in a wellbore |
BR0316278B1 (en) * | 2002-11-15 | 2013-04-02 | Method for drilling a borehole, system suitable for directionally drilling a borehole, hole bottom assembly, and suspension motor. | |
CA2512833C (en) * | 2003-01-15 | 2011-04-19 | Shell Canada Limited | Wellstring assembly |
WO2004094783A1 (en) * | 2003-04-24 | 2004-11-04 | Shell Internationale Research Maatschappij B.V. | Well string assembly |
US8016053B2 (en) * | 2007-01-19 | 2011-09-13 | Halliburton Energy Services, Inc. | Drill bit configurations for parked-bit or through-the-bit-logging |
-
2008
- 2008-09-05 US US12/204,937 patent/US7841400B2/en active Active
-
2009
- 2009-09-04 CA CA2735938A patent/CA2735938C/en not_active Expired - Fee Related
- 2009-09-04 AU AU2009289516A patent/AU2009289516B2/en not_active Ceased
- 2009-09-04 WO PCT/US2009/056039 patent/WO2010028244A2/en active Application Filing
- 2009-09-04 EP EP09812281.5A patent/EP2340347A4/en not_active Withdrawn
Non-Patent Citations (1)
Title |
---|
See references of EP2340347A4 * |
Also Published As
Publication number | Publication date |
---|---|
EP2340347A2 (en) | 2011-07-06 |
CA2735938A1 (en) | 2010-03-11 |
EP2340347A4 (en) | 2016-04-27 |
CA2735938C (en) | 2015-07-07 |
AU2009289516A1 (en) | 2010-03-11 |
US20100059290A1 (en) | 2010-03-11 |
US7841400B2 (en) | 2010-11-30 |
AU2009289516B2 (en) | 2014-09-18 |
WO2010028244A3 (en) | 2010-04-29 |
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