WO2010018366A2 - A controller for a downhole tool - Google Patents
A controller for a downhole tool Download PDFInfo
- Publication number
- WO2010018366A2 WO2010018366A2 PCT/GB2009/001949 GB2009001949W WO2010018366A2 WO 2010018366 A2 WO2010018366 A2 WO 2010018366A2 GB 2009001949 W GB2009001949 W GB 2009001949W WO 2010018366 A2 WO2010018366 A2 WO 2010018366A2
- Authority
- WO
- WIPO (PCT)
- Prior art keywords
- controller
- housing
- switching
- balls
- input parameters
- Prior art date
Links
- 238000000034 method Methods 0.000 claims abstract description 6
- 239000012530 fluid Substances 0.000 claims description 46
- 238000005553 drilling Methods 0.000 claims description 38
- 230000004044 response Effects 0.000 claims description 15
- 230000008859 change Effects 0.000 claims description 12
- 239000003381 stabilizer Substances 0.000 claims description 5
- 238000006073 displacement reaction Methods 0.000 claims description 2
- 239000000470 constituent Substances 0.000 description 2
- 230000000694 effects Effects 0.000 description 2
- 238000013022 venting Methods 0.000 description 2
- 230000009471 action Effects 0.000 description 1
- 230000015572 biosynthetic process Effects 0.000 description 1
- 239000004020 conductor Substances 0.000 description 1
- 238000010276 construction Methods 0.000 description 1
- 238000000605 extraction Methods 0.000 description 1
- 238000005755 formation reaction Methods 0.000 description 1
- 230000009467 reduction Effects 0.000 description 1
- 230000000717 retained effect Effects 0.000 description 1
- 230000007704 transition Effects 0.000 description 1
- 238000011144 upstream manufacturing 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
- E21B44/00—Automatic control systems specially adapted for drilling operations, i.e. self-operating systems which function to carry out or modify a drilling operation without intervention of a human operator, e.g. computer-controlled drilling systems; Systems specially adapted for monitoring a plurality of drilling variables or conditions
-
- 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
- E21B34/10—Valve arrangements for boreholes or wells in wells operated by control fluid supplied from outside the borehole
- E21B34/102—Valve arrangements for boreholes or wells in wells operated by control fluid supplied from outside the borehole with means for locking the closing element in open or closed position
-
- 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
- E21B17/00—Drilling rods or pipes; Flexible drill strings; Kellies; Drill collars; Sucker rods; Cables; Casings; Tubings
- E21B17/02—Couplings; joints
- E21B17/04—Couplings; joints between rod or the like and bit or between rod and rod or the like
- E21B17/06—Releasing-joints, e.g. safety joints
-
- G—PHYSICS
- G05—CONTROLLING; REGULATING
- G05B—CONTROL OR REGULATING SYSTEMS IN GENERAL; FUNCTIONAL ELEMENTS OF SUCH SYSTEMS; MONITORING OR TESTING ARRANGEMENTS FOR SUCH SYSTEMS OR ELEMENTS
- G05B19/00—Programme-control systems
- G05B19/02—Programme-control systems electric
- G05B19/04—Programme control other than numerical control, i.e. in sequence controllers or logic controllers
Definitions
- This invention relates to a controller for a downhole tool, and particularly but not exclusively to a controller for switching between functional modes of a downhole tool.
- control apparatus can, in certain technical fields, be actuated by electrical signals passed through electrical conductors or by telemetry and telecommand systems. Due to the severe conditions encountered in oil or gas wellbores it is desirable to provide a simple control means which is still capable of complex functionality.
- a drill string formed of lengths of drill pipe joined in end-to-end relationship, is fed down the wellbore. Whilst it may be desirable to actuate a device at an intermediate region along the length of the drill string, often the most important device to control is at that part of the drill string furthest from the operator, i.e. at or near the drill bit.
- the drill string can be regarded as a hollow duct, through which drilling fluid (also known as drilling mud) is passed under pressure.
- drilling fluid also known as drilling mud
- a steering stabiliser incorporated in the drill string.
- a stabiliser may have a plurality of elements capable of being moved radially outwardly either concentrically or eccentrically, under suitable actuation, so as to engage the internal surface of the wellbore.
- the elements and the housing with which they are associated are thus prevented from rotation relative to the wellbore, whereas the mandrel within the housing, forms part of the main duct of the drill string, and is free to continue to rotate. Conversely the housing may be locked to the mandrel.
- a controller for switching between functional modes of a downhole tool comprising: a switching device adapted for switching between a plurality of functional modes; and a sensing device adapted to sense a plurality of input parameters; wherein the switching device switches from a first of the functional modes to a second of the functional modes when the sensing device senses a predetermined state of at least two of the said input parameters.
- the controller can maintain or switch between functional modes of a downhole tool in response to more than one input parameter, wherein the action taken may depend upon the sequence of two or more different input parameters, i.e. pressure change before rotation or rotation change before pressure change.
- the switching device may only switch from a first of the functional modes to a second of the functional modes when the sensing device senses a predetermined state of at least two of the said input parameters.
- the switching device may switch functional modes in response to the sensing device sensing a predetermined change in one of said input parameters.
- the sensing device may sense the order in which the input parameters change, the switching device switching to or maintaining a first functional mode when the sensing means senses a first order and another functional mode when the sensing device senses a different order.
- the controller may comprise an outer housing and an inner mandrel rotatable within the outer housing, through which drilling fluid may pass.
- the inner mandrel may comprise a choke to provide a pressure difference inside the mandrel.
- the inner mandrel may be translated within the housing in the direction of flow and/or rotated, in response to said pressure difference.
- a resistive force may be provided to resist translation of the inner mandrel in response to said pressure difference.
- One of the said plurality of input parameters may be the rate of rotation of the downhole tool.
- One of the said plurality of input parameters may be a flow variable of a drilling fluid flowing through the downhole tool.
- the flow variable may be the pressure of the drilling fluid.
- the flow variable may be the flow rate of the drilling fluid.
- the functional modes may include any one of acting as a conventional drill pipe, opening ports, moving stabilisers, blades or sleeves, or a steering operation of the drill string or drill bit.
- the switching device may determine the functional mode from the axially translated and or rotated displacement of the mandrel within the housing.
- the switching device may be prevented from switching between functional modes unless one of the input parameters is at, under or exceeds a predetermined value.
- the input parameter may be at least one of the following: the rate of rotation of the downhole tool, the rate of rotation of the inner mandrel, the pressure of the drilling fluid, the flow rate of the drilling fluid, or the rate of pressure change of the drilling fluid.
- the switching device may be prevented from switching the functional mode by locking the inner mandrel relative to the housing to prevent axial and or rotational translation.
- the housing may comprise a plurality of circumferentially aligned balls or locking means which, when the downhole tool is rotating below a specific rate, protrude from the inner surface of the housing, if unobstructed, and which are flush with the inner surface of the housing when the downhole tool is rotating at or above this rate.
- a circumferential groove may be formed on the inner mandrel which receives said plurality of balls or locking means when rotation is below the specific rate and prevents axial translation and or rotation.
- the housing may comprise more than one circumferentially aligned set of bails or locking means.
- the balls or locking means may be provided in an inclined port in the housing wall.
- the balls or locking means may be spring loaded. Whilst the balls protrude from the inner surface of the housing, if the pressure of the drilling fluid is a predetermined value, then the balls may be prevented from becoming flush with the inner surface of the housing.
- the positions of the balls or locking means may relate to a specific functional mode.
- the inner mandrel may be locked relative to the housing by a locking means.
- the locking means may be controlled by a solenoid, hydraulics, or by electrical means.
- the switching device may be an actuator.
- the sensing device may be an electrical or electromagnetic device.
- a method of switching between functional modes of a downhole tool comprising-, a sensing step, wherein a plurality of input parameters are sensed; and a switching step, wherein the functional mode of the downhoie tool can be switched from a first functional mode to a second functional mode when a predetermined state of at least two of the said input parameters is sensed in the sensing step.
- the functional modes may be switched in response to the sensing of a predetermined change in one of said input parameters.
- the order in which the input parameters change may be sensed, and in the switching step a first functional mode may be maintained or switched to when the sensing step senses a first order and another functional mode may be maintained or switched to when the sensing step senses a different order.
- Figure 1 is a vertical cross-section of a controller for a downhoie tool according to a first embodiment of the present invention.
- Figure 2 is a vertical cross-section of a controller for a downhole tool according to a second embodiment of the present invention.
- Figure 3 is a second vertical cross-section of the controller of figure 1.
- Figure 4 is a second vertical cross-section of the controller of figure 2.
- Figure 5 is a perspective view of the controller according to the first embodiment in a first position.
- Figure 6 is a perspective view of the controller according to the second embodiment in a first position.
- Figure 7 is a perspective view of the controller according to the first embodiment during switching between a first and second position.
- Figure 8 is a perspective view of the controller according to the second embodiment during switching between a first and second position.
- Figure 9 is a flow chart showing the operation of a first embodiment of the controller.
- Figure 10 is a flow chart showing the operation of a second embodiment of the controller.
- a downhole tool comprising a controller 3 is generally indicated at 1.
- the downhole tool comprises a substantially cylindrical outer housing 2.
- an inner mandrel 4 which has a smaller outer diameter than the inner diameter of the outer housing 2.
- the mandrel 4 may be formed from a number of constituent parts which together form a substantially continuous inner surface 5.
- the inner surface 5 of the mandrel 4 defines a hollow duct 7, through which drilling fluid may pass.
- a plurality of substantially circumferentially aligned ports 8 which extend from an inner opening 9 in the inner surface of the housing towards an outer opening 11 in the outer surface of the outer housing 2.
- the ports 8 may be inclined and the outer opening 11 may be closed by a bolt, bung or other such means 13.
- a ball 10 of smaller outer diameter than the port 8 is positioned within the port 8.
- On the outer surface of the mandrel 4 is a circumferential groove 12.
- a lower housing 15 located between the outer housing 2 and the mandrel 4. The lower housing 15 is fixed to the outer housing 2.
- a resistive assembly 16 Located between the controller 3 and the lower housing 15 is a resistive assembly 16, generally in contact with an abutment shoulder 17 of the mandrel 4 and the upper edge 19 of the lower housing 15.
- the resistive assembly 16 may take any form which enables it to apply a resistive force between the controller 3 and the lower housing 15, for example, the resistive element 16 may be a spring as shown or an elastomeric element or a hydraulic assembly or any other such means capable of providing a resistive force.
- the lower housing may be incorporated into the outer housing 2 to form a one-piece construction.
- a plurality of ports 18 which may be aligned with a set of outer ports 20 or 22 which extend through the lower housing 15 and the outer housing 2, thus forming a plurality of open by-pass ports from the hollow duct 7 to the exterior of the downhole tool.
- the downhole tool may have a conventional lower housing connector 24 secured to one end region and may have a conventional upper housing connector 26 secured to the other end region.
- Figure 2 shows a second embodiment of the present invention, in which the downhole tool is substantially as in the first embodiment, but in the second embodiment the outer surface of the mandrel 4 has a plurality of circumferential grooves 12 and 14.
- the outer surface of the mandrel 4 may have one circumferential groove and the housing 2 may have several sets of ports 8 or the outer surface of the mandrel 4 may have a plurality of circumferential grooves and also several sets of ports 8.
- the outer housing may have a follower port 28 for locating a follower 30 in a substantially axial orientation slot 32.
- a substantially axial orientation slot 32 is shown here, it may be advantageous to use an orientation slot which maps any alternative path or to use a plurality of slots.
- the downhole tool 1 will be connected to a number of other drill pipes to form a drill string.
- drilling fluid is forced through the hollow duct 7 in the drill string and may be used to power a drill bit for drilling subterranean formations.
- the downhole tool will operate as a conventional drill pipe, allowing the drilling fluid to pass through the hollow duct 7.
- the choke 6, shown in figures 1 to 4 creates a pressure difference across itself when drilling fluid is flowing through the drill string.
- the balls 10 protrude into the circumferential groove 12 preventing the inner mandrel 4 from moving in response to the pressure difference created by the fluid flow.
- the pressure difference causes a small translation of the inner mandrel 4 relative to the outer housing 2 which locks the balls 10 between the opposing edges of the ports 8 and the circumferential groove 12 of these two components.
- the drill string Under certain circumstances it may be necessary to rotate the drill string. If the drill string is rotated when there is already a sufficient flow of drilling fluid through it, then, as previously described, the balls 10 will be locked between opposing edges of the ports 8 and the circumferential groove 12 and thus will prevent any relative translation between the inner mandrel 4 and the outer housing 2. In contrast, by rotating the drill string prior to applying a fluid flow, the balls 10 are free to move and will experience a centrifugal force which forces them radially along the ports 8 towards the outer opening 11 and therefore out of the circumferential groove 12.
- the ports 8 may be inclined, spring-loaded, or provided with other such biasing means so that a certain rotational speed is necessary before the balls 10 are expelled from the circumferential groove 12, and so that they are returned to the inner opening 9 once rotation is stopped or sufficiently reduced.
- the inner mandrel 4 can translate relative to the outer housing 2 by subsequently applying a fluid flow and thus creating a pressure difference across the choke 6. Under sufficient pressure (fluid flow), the force created is sufficient to overcome the resistive force created by the resistive assembly 16, and thus the inner mandrel translates relative to the ports 8 in the direction of the fluid flow, as is shown in figure 7 and 8.
- a second functional mode may be induced, for example in the present embodiment, the ports 18 of the inner mandrel 4 are aligned with the outer ports 22, forming a plurality of open ports from the hollow duct 7 to the exterior of the downhole tool, through which some or all of the drilling fluid may flow, by-passing the rest of the drill string.
- the resistive force created by the resistive assembly will be greater than the force created by the pressure difference and therefore there will be a net upwards force returning the inner mandrel to its original position. If the rotation of the drill string is then stopped the balls will again engage in the circumferential groove 12.
- the inner mandrel 4 may be provided with a translation stop so that over a certain pressure the inner mandrel 4 will not translate any further, thus maintaining the alignment of the ports 18 with the ports 22, and also, in the second embodiment, the ports 8 and the second circumferential groove 14.
- the first embodiment has been described wherein the positioning of the circumferential groove 12 allows the inner mandrel 4 to be locked relative to the outer housing 2 in a first position in which the inner mandrel 4 has not been translated relative to the outer housing 4.
- the circumferential groove may be positioned so that these components can be locked when they have been translated relative to one another due to the pressure difference created by the fluid flow, as achieved by groove 14 in the second embodiment.
- the resistive force created by the resistive assembly will be greater than the force created by the pressure difference and therefore there will be a net upwards force which acts to return the inner mandrel to its original position. However, this is prevented by the balls 10 which are locked between the opposing edges of the ports 10 and the circumferential groove 14 due to this force. Under these conditions, the drill string may be rotated without the balls being released and thus without the functional mode of the downhole tool 1 being changed. If the inner mandrel 4 is not provided with a translation stop as described above then the balls may also be locked as a result of excessive pressure.
- the balls 10 By stopping or sufficiently reducing rotation of the drill string following the reduction of fluid flow, the balls 10 will return towards the inner opening 9 as a result of the inclined or spring-loaded nature of the ports 8 and, when aligned with the circumferential groove 12, the balls 10 will engage with the circumferential groove 12 and lock the inner mandrel 4 in relation to the outer housing 2. Alternatively the drill string may continue to rotate and the inner mandrel remains free to move in response to the fluid flow.
- a follower assembly may be provided, as shown in figures 3 to 8.
- the follower port 28 does not, in contrast to the ports 8, allow the follower 30 to substantially move in response to the centrifugal force created when the drill string is rotated.
- a substantially vertical orientation slot 32 is provided so that unless the follower 30 is aligned with this slot, the follower will constrain the relative movement of the inner mandrel 4 relative to the outer housing 2. This ensures that, if a transition from a first circumferential groove to a second circumferential groove is to be made, that the inner mandrel 4 and outer housing 2 are maintained in the desired orientation. It is also contemplated to use several orientation slots, which may provide full alignment at each orientation or may provide varying degrees of alignment to allow the rate of by-pass to be controlled more effectively. Alternative orientation slots may be used which are not vertical.
- the functional mode of the downhole tool may be changed.
- the functional mode is changed from that of a standard drill pipe to a by-pass function, venting the drilling fluid through the lateral ports in the tool.
- other functional modes may be switched to.
- the translation and/or rotation of the inner mandrel 4 may cause a stabilizer to open from the outer housing 2, or may enable other functions required in drilling operations.
- the controller 3 has two main operations: sensing a plurality of input parameters and switching functional modes in response to the sensed input parameters.
- the choke 6 and balls 10 generally form a sensing device capable of sensing a plurality of input parameters. These parameters may be a flow variable of the drilling fluid and the rate of rotation of the downhole tool.
- the inner mandrel 4, choke 6, and resistive assembly 16 generally form a switching device capable of switching between functional modes.
- Figure 9 shows a flow chart of the functional modes achieved by altering the input parameters in a predetermined order.
- Figure 9 shows how turning on the drilling fluid flow and then the rotation of the tool, and vice versa, will result in different functional modes.
- the mandrel 4 may move from a first position, corresponding to circumferential groove 12, to a second position. In this position the functional mode of the downhole tool is changed.
- the mandrel 4 will return to the first position and thus to the original functional mode with the balls 10 again engaged in the circumferential groove 12.
- the balls will be locked between opposing edges of the ports 8 and the circumferential groove 12, and thus any subsequent rotation of the downhole tool will not cause the balls 10 to be expelled from the circumferential groove 12, so that the functional mode is maintained.
- the operation of the downhole tool comprising the controller in accordance with the second embodiment of the present invention is also shown in figure 10.
- the movement of the downhole tool from the first position to the second position is substantially as for the first embodiment.
- the mandrel may be maintained in this position by first stopping the rotation of the drill string. By doing so, the centrifugal force is removed and the balls 10 return to rest in the second circumferential groove 14. The mandrel will stay in the second position regardless of whether the flow of drilling fluid is stopped, reduced, or increased. If, however, the flow is stopped before the rotation of the drill string is stopped, then the mandrel will return to the first position as in the first embodiment.
- the mandrel cannot be released by rotating the tool.
- the mechanical means of the first and second embodiments may be replaced by or used in conjunction with electrical devices.
- the balls 10 may be replaced by an actuated locking means and an electrical or electromagnetic sensing device or devices may sense a predetermined state of any of the previously mentioned input parameters in which the locking means is activated.
- the locking means may be actuated by any known means, for example, a solenoid may be used to push and/or pull the locking means into the desired position.
- the choke and/or resistive assembly may be replaced by an actuator which causes the inner mandrel to translate relative to the outer housing when a predetermined state is sensed.
- the inner mandrel and outer housing assembly may be removed or altered if necessary or if enabled by adapting the mechanical means to electrical devices.
- the functional mode may be switched directly by an electrical device without the need for the translation of the inner mandrel.
Abstract
Description
Claims
Priority Applications (5)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
US13/058,799 US20110192612A1 (en) | 2008-08-13 | 2009-08-06 | Controller for a Downhole Tool |
BRPI0912594A BRPI0912594A2 (en) | 2008-08-13 | 2009-08-06 | controller for switching between functional modes of a well drilling tool and method for controlling a well drilling tool |
EP09784895A EP2324187A2 (en) | 2008-08-13 | 2009-08-06 | A controller for a downhole tool |
CA2733793A CA2733793A1 (en) | 2008-08-13 | 2009-08-06 | A controller for a downhole tool |
MX2011001703A MX2011001703A (en) | 2008-08-13 | 2009-08-06 | A controller for a downhole tool. |
Applications Claiming Priority (2)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
GB0814822A GB2462629A (en) | 2008-08-13 | 2008-08-13 | A Controller for a Downhole Tool |
GB0814822.3 | 2008-08-13 |
Publications (2)
Publication Number | Publication Date |
---|---|
WO2010018366A2 true WO2010018366A2 (en) | 2010-02-18 |
WO2010018366A3 WO2010018366A3 (en) | 2010-12-02 |
Family
ID=39790726
Family Applications (1)
Application Number | Title | Priority Date | Filing Date |
---|---|---|---|
PCT/GB2009/001949 WO2010018366A2 (en) | 2008-08-13 | 2009-08-06 | A controller for a downhole tool |
Country Status (7)
Country | Link |
---|---|
US (1) | US20110192612A1 (en) |
EP (1) | EP2324187A2 (en) |
BR (1) | BRPI0912594A2 (en) |
CA (1) | CA2733793A1 (en) |
GB (1) | GB2462629A (en) |
MX (1) | MX2011001703A (en) |
WO (1) | WO2010018366A2 (en) |
Families Citing this family (4)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
GB201201652D0 (en) | 2012-01-31 | 2012-03-14 | Nov Downhole Eurasia Ltd | Downhole tool actuation |
CN105637167B (en) | 2013-08-23 | 2017-07-25 | 哈利伯顿能源服务公司 | Stall proof mechanism |
GB2540391B (en) * | 2015-07-15 | 2021-02-17 | Nov Downhole Eurasia Ltd | Downhole apparatus |
US10876357B2 (en) * | 2019-03-26 | 2020-12-29 | Weber Schraubautomaten Gmbh | Flowing drilling apparatus and flow drilling process |
Citations (6)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US2505073A (en) * | 1949-03-08 | 1950-04-25 | Wayne N Sutliff | Grab tool |
US2878876A (en) * | 1956-10-03 | 1959-03-24 | Johnston Testers Inc | Well packing tool |
US3304874A (en) * | 1965-04-23 | 1967-02-21 | Lyles Cecil Ray | Well unloading process and apparatus therefor |
US3351144A (en) * | 1965-04-05 | 1967-11-07 | Baker Oil Tools Inc | Rotary expansible drilling apparatus with centrifugally operated latch |
US4997043A (en) * | 1990-05-04 | 1991-03-05 | Camco International Inc. | Well landing nipple and method of operation |
WO1993011334A1 (en) * | 1991-12-04 | 1993-06-10 | Charles Abernethy Anderson | Downhole stabiliser |
Family Cites Families (5)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US5034929A (en) * | 1989-08-02 | 1991-07-23 | Teleco Oilfield Services Inc. | Means for varying MWD tool operating modes from the surface |
GB2302607B (en) * | 1995-02-10 | 2000-06-28 | Baker Hughes Inc | Method and apparatus for remote control of wellbore end devices |
AU5248598A (en) * | 1996-10-22 | 1998-05-15 | Baker Hughes Incorporated | Drilling system with integrated bottom hole assembly |
US7243735B2 (en) * | 2005-01-26 | 2007-07-17 | Varco I/P, Inc. | Wellbore operations monitoring and control systems and methods |
AR064757A1 (en) * | 2007-01-06 | 2009-04-22 | Welltec As | COMMUNICATION / TRACTOR CONTROL AND DRILL SELECTION SWITCH SWITCH |
-
2008
- 2008-08-13 GB GB0814822A patent/GB2462629A/en not_active Withdrawn
-
2009
- 2009-08-06 EP EP09784895A patent/EP2324187A2/en not_active Withdrawn
- 2009-08-06 US US13/058,799 patent/US20110192612A1/en not_active Abandoned
- 2009-08-06 MX MX2011001703A patent/MX2011001703A/en not_active Application Discontinuation
- 2009-08-06 WO PCT/GB2009/001949 patent/WO2010018366A2/en active Application Filing
- 2009-08-06 CA CA2733793A patent/CA2733793A1/en not_active Abandoned
- 2009-08-06 BR BRPI0912594A patent/BRPI0912594A2/en not_active IP Right Cessation
Patent Citations (6)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US2505073A (en) * | 1949-03-08 | 1950-04-25 | Wayne N Sutliff | Grab tool |
US2878876A (en) * | 1956-10-03 | 1959-03-24 | Johnston Testers Inc | Well packing tool |
US3351144A (en) * | 1965-04-05 | 1967-11-07 | Baker Oil Tools Inc | Rotary expansible drilling apparatus with centrifugally operated latch |
US3304874A (en) * | 1965-04-23 | 1967-02-21 | Lyles Cecil Ray | Well unloading process and apparatus therefor |
US4997043A (en) * | 1990-05-04 | 1991-03-05 | Camco International Inc. | Well landing nipple and method of operation |
WO1993011334A1 (en) * | 1991-12-04 | 1993-06-10 | Charles Abernethy Anderson | Downhole stabiliser |
Also Published As
Publication number | Publication date |
---|---|
US20110192612A1 (en) | 2011-08-11 |
CA2733793A1 (en) | 2010-02-18 |
MX2011001703A (en) | 2011-04-28 |
GB2462629A (en) | 2010-02-17 |
WO2010018366A3 (en) | 2010-12-02 |
BRPI0912594A2 (en) | 2015-10-13 |
EP2324187A2 (en) | 2011-05-25 |
GB0814822D0 (en) | 2008-09-17 |
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