EP2655782A1 - Directional drilling - Google Patents
Directional drillingInfo
- Publication number
- EP2655782A1 EP2655782A1 EP11799098.6A EP11799098A EP2655782A1 EP 2655782 A1 EP2655782 A1 EP 2655782A1 EP 11799098 A EP11799098 A EP 11799098A EP 2655782 A1 EP2655782 A1 EP 2655782A1
- Authority
- EP
- European Patent Office
- Prior art keywords
- drill bit
- drilling fluid
- nozzles
- intermediate space
- solids
- 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.)
- Withdrawn
Links
- 238000005553 drilling Methods 0.000 title claims abstract description 122
- 239000012530 fluid Substances 0.000 claims abstract description 102
- 239000007787 solid Substances 0.000 claims abstract description 101
- 238000000034 method Methods 0.000 claims abstract description 25
- 238000005520 cutting process Methods 0.000 claims abstract description 9
- 230000000694 effects Effects 0.000 claims description 19
- 230000005291 magnetic effect Effects 0.000 claims description 13
- 238000011144 upstream manufacturing Methods 0.000 claims description 10
- 230000015572 biosynthetic process Effects 0.000 claims description 8
- 238000004891 communication Methods 0.000 claims description 7
- 239000002245 particle Substances 0.000 description 19
- 238000012986 modification Methods 0.000 description 6
- 230000004048 modification Effects 0.000 description 6
- 238000002474 experimental method Methods 0.000 description 5
- 230000035515 penetration Effects 0.000 description 5
- 238000005259 measurement Methods 0.000 description 4
- 239000010432 diamond Substances 0.000 description 3
- 230000003628 erosive effect Effects 0.000 description 3
- 238000012821 model calculation Methods 0.000 description 3
- 238000005299 abrasion Methods 0.000 description 2
- 230000000903 blocking effect Effects 0.000 description 2
- 239000010431 corundum Substances 0.000 description 2
- 229910052593 corundum Inorganic materials 0.000 description 2
- 229910003460 diamond Inorganic materials 0.000 description 2
- 238000007493 shaping process Methods 0.000 description 2
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 description 2
- 235000019738 Limestone Nutrition 0.000 description 1
- 229910000831 Steel Inorganic materials 0.000 description 1
- 230000001133 acceleration Effects 0.000 description 1
- 230000009471 action Effects 0.000 description 1
- 230000006978 adaptation Effects 0.000 description 1
- TZCXTZWJZNENPQ-UHFFFAOYSA-L barium sulfate Chemical compound [Ba+2].[O-]S([O-])(=O)=O TZCXTZWJZNENPQ-UHFFFAOYSA-L 0.000 description 1
- 229910052601 baryte Inorganic materials 0.000 description 1
- 239000010428 baryte Substances 0.000 description 1
- 238000005452 bending Methods 0.000 description 1
- 230000008901 benefit Effects 0.000 description 1
- 238000004364 calculation method Methods 0.000 description 1
- 230000001419 dependent effect Effects 0.000 description 1
- 238000007599 discharging Methods 0.000 description 1
- 230000005611 electricity Effects 0.000 description 1
- 238000005516 engineering process Methods 0.000 description 1
- 230000005294 ferromagnetic effect Effects 0.000 description 1
- 230000006870 function Effects 0.000 description 1
- 239000011019 hematite Substances 0.000 description 1
- 229910052595 hematite Inorganic materials 0.000 description 1
- 230000003993 interaction Effects 0.000 description 1
- LIKBJVNGSGBSGK-UHFFFAOYSA-N iron(3+);oxygen(2-) Chemical compound [O-2].[O-2].[O-2].[Fe+3].[Fe+3] LIKBJVNGSGBSGK-UHFFFAOYSA-N 0.000 description 1
- 239000006028 limestone Substances 0.000 description 1
- 239000007791 liquid phase Substances 0.000 description 1
- 230000007246 mechanism Effects 0.000 description 1
- 239000000203 mixture Substances 0.000 description 1
- 230000005298 paramagnetic effect Effects 0.000 description 1
- 238000007790 scraping Methods 0.000 description 1
- 238000007873 sieving Methods 0.000 description 1
- 239000010959 steel Substances 0.000 description 1
- 238000012360 testing method Methods 0.000 description 1
- 238000012546 transfer Methods 0.000 description 1
Classifications
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B7/00—Special methods or apparatus for drilling
- E21B7/04—Directional drilling
- E21B7/06—Deflecting the direction of boreholes
- E21B7/065—Deflecting the direction of boreholes using oriented fluid jets
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B7/00—Special methods or apparatus for drilling
- E21B7/18—Drilling by liquid or gas jets, with or without entrained pellets
Definitions
- the present invention relates to a method of
- RSS rotary steerable systems
- PDC polycrystalline diamond compact
- Some directional drilling systems and methods use drill bits wherein the nozzles are specially adapted so as to obtain a directional drilling effect.
- abrasive particles This can be done by modulating the mass flow rate of the abrasive particles, for instance by modulating the quantity of the abrasive particles in the abrasive jet, or by modulating the velocity of the abrasive particles, which can be done for instance by modulating an acceleration pressure drop of the fluid in the jet means, or by a combination thereof.
- each of the first and second nozzles having a nozzle inlet for fluid
- step of modifying solids concentration comprises directing drilling fluid into a first area of the
- the directing of fluid towards the first area will cause transfer of drilling fluid with a higher concentration of solids to that nozzle, compared to the second nozzle that has its inlet in another area of the intermediate space.
- the inlet of the second nozzle will be in the first area towards which fluid is preferentially directed, and now receives a higher solids concentration, both compared to the first nozzle at the second moment in time as well as to the second nozzle at the first moment in time.
- a flow directing means having an outlet member for directing drilling fluid, and the method further comprises maintaining the outlet member in a geostationary position during at least one rotation of the drill bit. This is a particularly simple means of achieving an increased solids concentration towards consecutive nozzle inlets during rotation.
- a motor can be provided, controlled to orient the flow directing means as desired.
- the flow directing means can be rotatably arranged in the drill string, and shaped so as to rotate in opposite direction with respect to the drill string when passing drilling fluid down the drill string.
- shaping can include providing vanes, fins or similar.
- a brake means for the rotation of the flow directing means can be provided, and maintaining the flow directing means in a geostationary position then comprises operating the break means so as to slow the rotation of the flow directing means to compensate the opposite rotation of the drill string.
- the flow directing means can further include an electrical generator for converting hydraulic energy of the drilling fluid or rotational energy of the flow directing means into electricity, which can for example power a downhole measurement and/or control unit used for the directional drilling.
- a solids concentration means is provided for increasing the concentration of solids in a drilling fluid portion.
- the solids concentration means can be arranged to apply a rotating magnetic field to the drilling fluid.
- This can for example be a rotating magnet arrangement, e.g. a permanent magnet or an electromagnet.
- rotating magnet arrangement can for example be combined with a rotating flow diverter, to enhance the solids concentration effect.
- a rotating magnetic field can also be provided without moving parts, by arranging an
- electromagnet arrangement in and/or around the flow path of drilling fluid, comprising a plurality of
- concentration means can comprise a curved flow path so as to effectuate a concentration due to centrifugal forces.
- a flow guide is provided in the intermediate space, which is rotated together with the drill bit, the flow guide comprising first and second channels each co-operating during time periods of the rotation at an upstream end with the outlet member, depending on the relative rotational position the outlet member and the drill bit, and at a downstream end with the first and second nozzle inlets, respectively.
- This embodiment allows the outlet member directing the fluid to interface with the upstream end of the flow guide, which can be near the inlet port of the drill bit, which may be more convenient than interfacing directly with an area of nozzle inlets in the intermediate space some distance into the drill bit.
- the system comprising:
- a drill bit connected to the drill string element, the drill bit comprising a bit body, mechanical cutting means forming a bit face, an inlet port for receiving the drilling fluid from the drill string element, a plurality of nozzles for ejecting the drilling fluid, which nozzles are arranged at different azimuthal positions with respect to the bit face, and an intermediate space between the inlet port and the plurality of nozzles, each of the nozzles having a nozzle inlet for fluid
- a diverter for directing at least part of the solids to a first area of the intermediate space, from which first area consecutively one of the nozzle inlets extends during relative rotation of the drill bit with respect to the diverter, as compared with a second area of the intermediate space.
- the flow directing means comprising an outlet member in rotatable arrangement with respect to the drill bit, the outlet member being arranged to direct drilling fluid into a first area of the intermediate space from which
- consecutively one of the first and second nozzle inlets extends during a relative rotation of the outlet member with respect to the drill bit;
- the outlet member can in particular be a flow diverter.
- system comprises a flow guide provided in the intermediate space in a rotatably locked configuration with the drill bit, the flow guide
- the magnet comprises a magnet for diverting said part of the solids towards the first area of the intermediate space.
- the magnet can be a rotatable permanent magnet or an
- electromagnet with a driver unit capable of producing a rotating magnetic field.
- the diverter can comprise a curved flow path.
- At least part of the diverter and/or flow directing means and/or the flow guide can be retrievable through the drill string element. This makes it possible to conduct directional drilling only during certain periods of a drilling operation.
- retrievable, components are also insertable or reinsertable .
- Figure 1 schematically shows an embodiment of system for directional drilling a borehole in an earth formation in accordance with the invention
- Figure 2 schematically shows an electromagnetic brake arrangement
- Figure 3a and 3b show schematic views down the borehole as in Figure 1, for two moments in time;
- Figure 4 schematically shows another embodiment of a system for directional drilling a borehole in an earth formation in accordance with the invention
- Figure 5 schematically shows a cross-sectional view of the flow guide in Figure 4 ;
- Figure 6 shows the result of a model calculation of drilling radius in dependence of a differential hole making (DHM) effect
- Figures 7a and 7b schematically show an embodiment of a deflection means alternative to outlet member 45 in Figures 1 and 4, in perspective and top view;
- FIGS 8a and 8b schematically show alternative methods and means for solids diversion.
- the system 1 comprises a drill bit 10 connected to a sub 14, which is a part of drill string 16 extending to the earth's surface.
- a drill collar 17 is shown connected to the upper end of sub 14 as a further part of the drill string 16.
- a length of drill string above the drill bit 10 is referred to as a drill string element, and can be the entire drill string.
- the solids diverter in this embodiment is a flow directing means 42 comprising an outlet member 45, connected via support member 46 and shaft 48 to a rotation means schematically shown as 50, and controlled by control unit 52 for controlling relative rotation of the outlet member with respect to the drill bit 10.
- the support member 46 is arranged such that it allows drilling fluid to pass down the interior of the drill string towards the inlet port 30.
- the outlet member 45 in this embodiment is a flow diverter, shown as a flat plate as seen from the side, but it can also have other shapes such as a curved lip or a channel.
- the outlet member 45 in this embodiment extends via the inlet port 30 into the intermediate space 32, and this way delivers drilling fluid in a direction towards a first area 55 of the intermediate space 32.
- the first inlet channel 36 to first nozzle 35 extends from the first area 55
- the second inlet channel 39 to second nozzle 38 extends from the second area 56 which second area is outside of the area towards which drilling fluid is directed.
- the second inlet channel 39 to second nozzle 38 extends from the first area 55. Areas 55 and 56 are regarded as geostationary.
- the control unit 52 is adapted to obtain orientation data, such as from external, connected or integrated measurement devices, e.g. MWD devices, and/or via
- the rotation means 50 can for example be an active drive motor.
- Another option is shaping a part of the flow
- FIG 2 a schematic electromagnetic brake arrangement for the rotation means is shown, in a view down the borehole 3 as in Figure 1.
- a stator 60 is arranged, which is rotatably locked to the sub 14.
- the stator can also be integrally formed with the sub.
- a rotor 64 is rotatably arranged with respect to the stator 60/sub 14.
- the rotor 64 comprises means , e.g. a vane, fin or rib, exerting a torque when fluid flows along and is deflected, so as to rotate the rotor
- the stator can comprise the permanent magnet arrangement, and the rotor the electromagnetic coil arrangement interacting with the permanent magnet arrangement during relative rotation so as to create a voltage over electrical poles of the electromagnetic coil arrangement, and thereby electrical energy.
- This energy can be dissipated in a load.
- the load can e.g. be a resistor. Instead of dissipating the energy as heat, it can also at least partly be used for powering other electrical equipment, directly or by loading a battery.
- the resistance to rotation can be controlled, and thereby the electromagnetic brake can be adjusted such that the rotations 64 and 68 compensate each other, so that the rotor 64 to which the outlet member 45 of the embodiment of Figure 1 is connected, remains geostationary.
- the outlet member causes a diversion of solids in the
- the flow directing means 42 in this embodiment can be retrieved to surface upwardly through the interior of the drill string 16. Also, the flow directing means 42 can be introduced through the drill string from surface, for instance to replace the flow directing means after retrieval thereof.
- drilling fluid comprising solids is pumped down the interior of drill string 16.
- the solids can be solids known to be used in
- solids can comprise solids that can be deflected in a magnetic field, e.g.
- Solids are preferably present as particles of a particle size that does not block passages or nozzles in the drill string and/or drill bit, but provides
- Particles included in the drilling fluid for abrasive effect have suitably a minimum particle size.
- at least 90 % of these particles, preferably substantially all of these particles, more preferably all of these particles do not pass through a 20 pm sieve, in particular a 32 pm sieve, more in particular a 450 pm sieve.
- drilling fluid is directed towards the first area 55 of the intermediate space 32.
- the drilling fluid is
- Figures 3a and 3b schematic views down the borehole 3 as in Figure 1 are shown, for two different moments in time.
- the Figures show four sectors of the borehole bottom 28, including first sector 81 and second sector 82, separated by third sector 83 and fourth sector 84.
- a first nozzle 35 with first inlet channel 36 is located in first angular sector 81 of the borehole bottom near point A in the formation 5.
- the direction of solids diversion 70 is shown instead of the flow diverter 45, or of any other means used for solids diversion.
- the solids concentration towards first area 55 is increased by inertia, and from this area the first inlet channel 36 extends at this moment in time.
- the second nozzle 38 is located in second angular sector 82 opposite sector 81 of the borehole bottom and receives fluid from the second area 56 of the intermediate space, which in the area receiving a relatively lower solids concentration than the first area 55.
- Figure 3b shows a later moment in time, when the drill bit has turned so that the second nozzle 38 with inlet channel 39 is in the first sector 81 near point A, and receives drilling fluid with higher solids concentration from the area 55 of the intermediate space 32 that is considered to be
- the first nozzle 35 now is in the second sector 82 and receives fluid from the second area 56.
- the first and second areas can be analogously defined with respect to such circular cross-section instead of the borehole bottom.
- FIG. 4 there is shown a further embodiment of a method and system 101 for directional drilling a borehole 3 in an earth formation 5 in
- the drill bit 110 is a roller-cone drill bit having three roller cones of which only two are shown with reference numerals 111,112. Roller cone 112 and its supporting leg are dashed, to indicate that this cone is behind the paper plane.
- the third roller cone (not shown) would be generally in front of roller cone 112.
- a nozzle is associated, first nozzle 35 with first roller cone 111, second nozzle 38 with second roller cone 112, and a third nozzle with the third roller cone (not shown) .
- the nozzles communicate via inlet channels with the intermediate space 32 of the bit 110.
- a flow guide 133 is
- the flow guide 133 in this embodiment is an insert that is adapted to and can be placed in a
- the flow guide 133 is arranged such that it is rotatably locked to the bit, i.e. it rotates with the drill bit 110.
- the flow guide 133 is arranged such that it is rotatably locked to the bit, i.e. it rotates with the drill bit 110.
- FIG. 133 comprises a first channel 134 co-operating at a downstream end 135 with the inlet to the first inlet channel 36, and a second channel 137 co-operating at its downstream end 138 with second inlet channel 39.
- a cross- sectional view of the flow guide 133 is shown in Figure
- the flow guide 133 in this embodiment can be
- the deflection means can be arranged in principle instead of the outlet member
- the deflection means acts as a solids diverter, due to the higher inertia of solids with higher density as discussed hereinabove.
- Deflection means 101 has an upstream end 103 for receiving fluid flowing along the drill string element, a downstream end 105 forming a non- axial outlet 106 for fluid, and a flow path 108 for fluid between the upstream and downstream ends. The direction of fluid flow is indicated by arrow 109.
- the deflection means is rotatable about the axis of the drill string element in which it is arranged during normal operation, which drill string element is not shown but for example similar to sub 14 discussed above.
- the axis of the drill string element 18 coincides with the axis 110 of the deflection means 101.
- the deflection means 101 of this embodiment comprises a deflection member 112 forming an at least partly helical flow channel 113 for fluid, coinciding with the flow 108 path.
- the flow path is arranged such that fluid flowing from the upstream end to the downstream end exerts a torque about the axis 110.
- a geostationary magnetic field can be used to direct solids towards first area 55.
- a geostationary magnetic field can be used to direct solids towards first area 55.
- One schematic embodiment for this is shown in Figure 8a, and is based on the electromagnetic brake of Figure 2.
- a magnet 72 can be arranged instead of the flow diverter with outlet member 45.
- the operation of the brake is in principle as discussed with reference to Figure 2, but now the magnet diverts solids in the direction 70.
- the magnet 72 is suitably a permanent magnet so that no power is required .
- FIG 8b a further embodiment of a solids diverter is schematically shown.
- the solids diverter 80 of this embodiment comprises a plurality of
- electromagnetic coils 82 which are connected to a power source control unit, which energizes individual coils as a function of time such that an effective magnetic field is obtained that is rotating relatively opposite the rotation 68 of the sub 14, thereby also providing a geostationary solids deflection in the direction 70.
- An advantage of this embodiment is that it does not include mechanically rotating parts, but it requires an electric power source.
- DHM can be defined as the difference, expressed in percent, between the rates of penetration at the opposite sides (diametrically opposite points) . Calculations were performed for a
- This model calculation does not take the stiffness of the bottom part of the drill string/bottom hole assembly (BHA) into account. In the practice of the invention this stiffness can determine the minimum radius that can be drilled; if the drill bit has a tendency for a smaller radius, it can set the drilling system into a mode to drill the minimum radius determined by the BHA.
- Drilling was performed at 60 rotations per minute (RPM) , and at a downhole pressure of 10 MPa, with a pressure drop over the bit of 7 MPa and a flow rate of drilling fluid of 700 1/min.
- RPM rotations per minute
- ROP was measured with solids present in the drilling fluid (ROP solids) .
- ROP was also measured without solids, before and after the measurement with solids, and the average of these measurements is given as "ROP no solids" in Table 1 as well.
- the rate of penetration depends on weight-on-bit applied. This dependency is typically substantially linear for a range of WOB, and with the method of the invention it is preferred to operate in that linear regime.
- the flow rate of drilling fluid through the nozzle receiving a higher solids concentration is increased at the same time. It has been found that for a PDC bit the increased flow rate also increases the rate of penetration,
- concentration is modulated without influencing flow rate. If no directional drilling is desired, this can be achieved by taking the solids diverter out of a
Landscapes
- Life Sciences & Earth Sciences (AREA)
- Engineering & Computer Science (AREA)
- Geology (AREA)
- Mining & Mineral Resources (AREA)
- Physics & Mathematics (AREA)
- Environmental & Geological Engineering (AREA)
- Fluid Mechanics (AREA)
- General Life Sciences & Earth Sciences (AREA)
- Geochemistry & Mineralogy (AREA)
- Earth Drilling (AREA)
Abstract
Description
Claims
Priority Applications (1)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
EP11799098.6A EP2655782A1 (en) | 2010-12-22 | 2011-12-20 | Directional drilling |
Applications Claiming Priority (3)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
EP10196484 | 2010-12-22 | ||
EP11799098.6A EP2655782A1 (en) | 2010-12-22 | 2011-12-20 | Directional drilling |
PCT/EP2011/073386 WO2012084934A1 (en) | 2010-12-22 | 2011-12-20 | Directional drilling |
Publications (1)
Publication Number | Publication Date |
---|---|
EP2655782A1 true EP2655782A1 (en) | 2013-10-30 |
Family
ID=43901253
Family Applications (1)
Application Number | Title | Priority Date | Filing Date |
---|---|---|---|
EP11799098.6A Withdrawn EP2655782A1 (en) | 2010-12-22 | 2011-12-20 | Directional drilling |
Country Status (7)
Country | Link |
---|---|
US (1) | US20130292181A1 (en) |
EP (1) | EP2655782A1 (en) |
CN (1) | CN103328755B (en) |
AU (1) | AU2011347447B2 (en) |
CA (1) | CA2822327A1 (en) |
EA (1) | EA201300732A1 (en) |
WO (1) | WO2012084934A1 (en) |
Families Citing this family (11)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
CN105164367B (en) * | 2013-04-29 | 2018-12-14 | 国际壳牌研究有限公司 | Method and system for directed drilling |
CN105164361B (en) | 2013-04-29 | 2018-04-24 | 国际壳牌研究有限公司 | Insert and the method for directed drilling |
CN105164366B (en) * | 2013-04-29 | 2018-10-26 | 国际壳牌研究有限公司 | Method and system for directed drilling |
US20150047911A1 (en) * | 2013-08-15 | 2015-02-19 | Smith International, Inc. | Using magnetic force/field for drill bits and other cutting tools |
US9765618B2 (en) | 2015-01-28 | 2017-09-19 | Joy Mm Delaware, Inc. | Cutting bit assembly |
WO2016186660A1 (en) | 2015-05-19 | 2016-11-24 | Halliburton Energy Services, Inc. | Down-hole communication across a mud motor |
WO2019002436A1 (en) | 2017-06-30 | 2019-01-03 | Shell Internationale Research Maatschappij B.V. | Rotary steerable drill string |
WO2019089733A1 (en) * | 2017-10-31 | 2019-05-09 | Otto Torpedo Company | Radial conduit cutting system |
NL2024001B1 (en) * | 2019-10-11 | 2021-06-17 | Stichting Canopus Intellectueel Eigendom | Method and system for directional drilling |
NL2026757B1 (en) | 2020-10-23 | 2022-06-17 | Stichting Canopus Intellectueel Eigendom | Device and method for concentrating particles within a stream |
CN113338808A (en) * | 2021-07-13 | 2021-09-03 | 中国石油大学(北京) | Main power rotary cutting wheel drill bit |
Family Cites Families (13)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US2075064A (en) * | 1936-05-26 | 1937-03-30 | James H Schumacher | Direction control mechanism for well drilling tools |
US4211292A (en) | 1978-07-27 | 1980-07-08 | Evans Robert F | Borehole angle control by gage corner removal effects |
US4619335A (en) * | 1984-08-16 | 1986-10-28 | Mccullough Doyle W | Enhanced circulation drill bit |
US4637479A (en) | 1985-05-31 | 1987-01-20 | Schlumberger Technology Corporation | Methods and apparatus for controlled directional drilling of boreholes |
GB2190411B (en) * | 1986-05-16 | 1990-02-21 | Shell Int Research | Apparatus for directional drilling. |
US5314030A (en) * | 1992-08-12 | 1994-05-24 | Massachusetts Institute Of Technology | System for continuously guided drilling |
GB2284837B (en) | 1993-12-17 | 1997-11-12 | Anadrill Int Sa | Directional drilling method and apparatus |
AUPO062296A0 (en) * | 1996-06-25 | 1996-07-18 | Gray, Ian | A system for directional control of drilling |
MY123696A (en) * | 1999-04-28 | 2006-05-31 | Shell Int Research | Abrasive jet drilling assembly |
EP1453627A4 (en) * | 2001-12-05 | 2006-04-12 | Baker Hughes Inc | Consolidated hard materials, methods of manufacture, and applications |
AR045022A1 (en) * | 2003-07-09 | 2005-10-12 | Shell Int Research | SYSTEM AND METHOD FOR PERFORATING AN OBJECT |
US8715506B2 (en) * | 2009-07-23 | 2014-05-06 | National Oilwell Varco, L.P. | Apparatus and method for density separator for drilling fluid |
AU2010334867B2 (en) * | 2009-12-23 | 2015-10-01 | Shell Internationale Research Maatschappij B.V. | Method of drilling and abrasive jet drilling assembly |
-
2011
- 2011-12-20 US US13/996,472 patent/US20130292181A1/en not_active Abandoned
- 2011-12-20 EP EP11799098.6A patent/EP2655782A1/en not_active Withdrawn
- 2011-12-20 WO PCT/EP2011/073386 patent/WO2012084934A1/en active Application Filing
- 2011-12-20 AU AU2011347447A patent/AU2011347447B2/en not_active Ceased
- 2011-12-20 CA CA2822327A patent/CA2822327A1/en not_active Abandoned
- 2011-12-20 CN CN201180061667.7A patent/CN103328755B/en not_active Expired - Fee Related
- 2011-12-20 EA EA201300732A patent/EA201300732A1/en unknown
Non-Patent Citations (2)
Title |
---|
None * |
See also references of WO2012084934A1 * |
Also Published As
Publication number | Publication date |
---|---|
US20130292181A1 (en) | 2013-11-07 |
EA201300732A1 (en) | 2013-11-29 |
CA2822327A1 (en) | 2012-06-28 |
AU2011347447A1 (en) | 2013-06-20 |
CN103328755A (en) | 2013-09-25 |
CN103328755B (en) | 2015-11-25 |
AU2011347447B2 (en) | 2015-07-09 |
WO2012084934A1 (en) | 2012-06-28 |
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18D | Application deemed to be withdrawn |
Effective date: 20170926 |