US20140231096A1 - Downhole tool control - Google Patents

Downhole tool control Download PDF

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Publication number
US20140231096A1
US20140231096A1 US14/182,132 US201414182132A US2014231096A1 US 20140231096 A1 US20140231096 A1 US 20140231096A1 US 201414182132 A US201414182132 A US 201414182132A US 2014231096 A1 US2014231096 A1 US 2014231096A1
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US
United States
Prior art keywords
flow
tool
piston
configuration
operating
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Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
Abandoned
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US14/182,132
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English (en)
Inventor
Alan Martyn Eddison
Current Assignee (The listed assignees may be inaccurate. Google has not performed a legal analysis and makes no representation or warranty as to the accuracy of the list.)
NOV Downhole Eurasia Ltd
Original Assignee
NOV Downhole Eurasia Ltd
Priority date (The priority date 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 date listed.)
Filing date
Publication date
Application filed by NOV Downhole Eurasia Ltd filed Critical NOV Downhole Eurasia Ltd
Assigned to NOV DOWNHOLE EURASIA LIMITED reassignment NOV DOWNHOLE EURASIA LIMITED ASSIGNMENT OF ASSIGNORS INTEREST (SEE DOCUMENT FOR DETAILS). Assignors: EDDISON, ALAN MARTYN
Publication of US20140231096A1 publication Critical patent/US20140231096A1/en
Abandoned legal-status Critical Current

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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
    • E21B23/00—Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells
    • E21B23/04—Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells operated by fluid means, e.g. actuated by explosion
    • 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
    • E21B34/00—Valve arrangements for boreholes or wells
    • E21B34/06—Valve arrangements for boreholes or wells in wells
    • E21B34/08—Valve arrangements for boreholes or wells in wells responsive to flow or pressure of the fluid obtained
    • 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
    • E21B23/00—Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells
    • E21B23/04—Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells operated by fluid means, e.g. actuated by explosion
    • E21B23/042—Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells operated by fluid means, e.g. actuated by explosion using a single piston or multiple mechanically interconnected pistons
    • 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
    • E21B23/00—Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells
    • E21B23/004—Indexing systems for guiding relative movement between telescoping parts of downhole tools
    • E21B23/006—"J-slot" systems, i.e. lug and slot indexing mechanisms
    • 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
    • E21B23/00—Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells
    • E21B23/04—Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells operated by fluid means, e.g. actuated by explosion
    • E21B23/0413—Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells operated by fluid means, e.g. actuated by explosion using means for blocking fluid flow, e.g. drop balls or darts
    • 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
    • E21B34/00—Valve arrangements for boreholes or wells
    • E21B34/06—Valve arrangements for boreholes or wells in wells
    • 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
    • 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

Definitions

  • This invention relates to the control of a downhole tool or device, utilizing fluid pressure or flow.
  • Flow through a restriction in a spring-loaded sleeve may be utilized to create a pressure differential across the sleeve, the pressure differential moving the sleeve downwards from a first or no-flow position, against the action of the spring, to a second or flow position associated with activation or actuation of an associated device.
  • the movement of the sleeve may be controlled by means of a cam arrangement, such as a J-slot or cam track and cam follower pin.
  • the cam track may be configured to provide for two or more flow positions.
  • One flow configuration may be associated with actuation of an associated device, and in another flow configuration the device may remain inactive.
  • the operator may achieve these positions simply by cycling the surface pumps on and off. However, if the pumps are cycled for other reasons, such as to make a connection at surface, the operator may have to cycle the pumps a number of times to achieve or regain the desired configuration. There is also a risk that the operator will have a mistaken belief that a tool is in a certain configuration when it is not, which may have significant operational and safety implications.
  • U.S. Pat. No. 6,289,999 describes a fluid flow control device in which an operator may select a path associated with a flow-through mode or a path associated with a valve control mode. The selection is made by the operator remotely tracking the movement of a lug along a ratchet path following the actuation of fluid pumps. At a certain relative position of the lug on the ratchet path, shutting off the fluid pumps causes the lug to track back along the ratchet path, a corner in the ratchet path then deflecting the lug from a first operational mode path into a second path.
  • a downhole tool comprising:
  • the tool may be reconfigured between the different configurations in any appropriate order or sequence.
  • the tool may be provided in the no-flow configuration and then reconfigured to the intermediate configuration by activating surface pumps to circulate fluid through the tool at the intermediate flow-rate and axially translate the piston from the no-flow position to the intermediate position.
  • the axial translation of the piston will comprise an initial occlusional stage and a secondary transitional stage.
  • the flow-rate may subsequently be reduced to zero to return the tool to the no-flow configuration, or alternatively the flow-rate may be increased to the operating flow-rate to reconfigure the tool to the operating configuration.
  • the tool may be provided in the operating configuration and then reconfigured to the intermediate configuration by reducing the flow-rate through the tool from the operating flow-rate to the intermediate flow-rate and permitting the piston to assume the intermediate position.
  • the tool may be directly reconfigured from the no-flow configuration to the operating configuration by increasing the flow-rate directly from zero to the operating flow-rate without seeking to maintain the flow-rate at an intermediate level and thus attain and then maintain the intermediate configuration.
  • decreasing the flow-rate directly from the operating flow-rate to zero may directly reconfigure the tool from the operating configuration to the no-flow configuration.
  • the provision of the occlusional stage of axial translation of the piston between the no-flow configuration and the intermediate position may provide the operator with assurance that the piston has moved to the intermediate position and achieved the desired function, for example a tool activation or setting associated with the intermediate tool configuration.
  • a relatively small flow-rate will ensure that the intermediate configuration is achieved.
  • an intermediate flow-rate within a relatively broad range will achieve the desired intermediate configuration.
  • the interaction of the flow-restriction and the piston serves to facilitate attaining the intermediate configuration from the operating configuration, the step-change in flow area at the transitional stage tending to maintain the tool in the intermediate configuration over a range of flow-rates below the operating flow-rate.
  • the second axial extent of the transitional stage may be less than the first axial extent of the occlusional stage.
  • the reconfiguration of the tool to the operating configuration may involve a degree of translation of the piston from the no-flow configuration greater than the degree of translation of the piston from the no-flow position to the intermediate position.
  • the method may comprise removing the flow-restriction from the tool, moving the restriction out of cooperating engagement with the piston, or otherwise reconfiguring the restriction, to improve access to the tool throughbore below the restriction location or to increase the flow area through the tool.
  • a flow-restricting member provided in the body may be retrievable or otherwise removable.
  • the order or sequence of reconfiguration of the tool may be controlled or guided, for example a cam or J-slot arrangement may be provided between the piston and a tool body.
  • one element of the tool may define a cam track and another element may define a cam follower, such as a pin.
  • the cam track may define alternative or multiple paths or branches and the path followed may be operator-determined by selecting a particular sequence of configurations.
  • the method may further comprise:
  • a downhole tool having utility in an operator-selectable intermediate configuration and in an operating configuration, the tool comprising:
  • the piston and flow-restriction cooperating to define an intermediate flow area, axial translation of the piston between the no-flow position and the intermediate position comprising an occlusional stage of a first axial extent during which the piston and the flow-restriction cooperate to substantially occlude the through bore and a transitional stage of a second axial extent during which the piston and the flow-restriction cooperate to provide a step-change in flow area;
  • the flow restriction may take any appropriate form.
  • the flow restriction may include an elongate flow-restricting member mounted in the body.
  • the flow-restricting member may be coaxial with the piston.
  • the flow-restricting member may be received within the piston.
  • the flow-restricting member may be axially movable relative to the piston.
  • the flow-restricting member may include a substantially cylindrical portion which cooperates with a complementary passage or restriction in the piston when the tool is in the no-flow configuration and during the occlusional stage of translation between the no-flow position and the intermediate position.
  • the transitional stage of translation occurs when the cylindrical portion of the flow-restricting member and the complementary passage or restriction separate to provide a step-change in flow area.
  • flow-restricting member and piston may be utilized to achieve a similar effect, such as a flow-restricting member with a stepped profile which provides the step change in area.
  • the flow restriction may include an elongate flow restriction or probe mounted on the piston which cooperates with a complementary passage or restriction in the body.
  • the piston may define a flow restriction, for example a nozzle, such that increasing flow through the piston creates an increasing axial fluid pressure force on the piston. If the piston is biased towards the no-flow position, increasing flow may tend to increase the distance of the piston from the no-flow position.
  • the piston flow restriction may cooperate with a body-mounted flow-restricting member.
  • the piston and body may cooperate to define a differential piston, wherein an area of the piston is exposed to internal tool pressure, which may be drill string pressure, and an oppositely directed area of the piston is exposed to external tool pressure, which may be annulus pressure. Accordingly, a higher internal pressure may be utilized to urge the piston towards the operating position.
  • the method may further comprise:
  • FIGS. 1 a , 1 b , 1 c and 1 d are schematic illustrations of a tool in accordance with a first embodiment of the present invention
  • FIGS. 2 a , 2 b and 2 c are schematic illustrations of a tool in accordance with a second embodiment of the present invention.
  • FIG. 3 is a schematic illustration of a cam track of a tool in accordance with an embodiment of the present invention.
  • FIGS. 4 a , 4 b and 4 c are schematic illustrations of a tool in accordance with another embodiment of the present invention.
  • FIG. 5 is a schematic illustration of a tool in accordance with a further embodiment of the present invention.
  • FIGS. 1 a , 1 b , 1 c , and 1 d of the drawings are schematic illustrations of a tool 10 in accordance with a first embodiment of the present invention.
  • the tool 10 is intended to form part of a downhole tubular string, such as a drill string, tool string, or the like. Accordingly, the tool 10 includes a cylindrical body 12 having appropriate end connections (not shown) for incorporation in the associated string.
  • a tubular piston 14 including an internal flow restriction in the form of a nozzle 16 , such that circulation or flow of fluid in the normal direction, that is from surface towards the distal end of the string, creates a fluid pressure force across the piston 14 , tending to translate the piston downwards, against the action of a compression spring 18 .
  • a cylindrical flow restriction in the form of a probe 20 is mounted to the body 12 and, with the piston 14 in the raised position ( FIG. 1 c ), the probe 20 extends into the piston 14 and through the nozzle 16 .
  • the probe 20 is coaxial with the piston 14 and has an outer diameter only slightly smaller than the internal diameter of the nozzle 16 . Accordingly, while the probe 20 is located within the nozzle 16 the tool body is substantially occluded.
  • FIG. 1 a illustrates the relative positions of the tool elements in a typical operating configuration, with fluid being pumped through the tool 10 and the associated string at a normal operational rate such as required during, for example, a drilling operation.
  • the fluid pressure differential created across the nozzle 16 is sufficient to move the piston 14 to its lowermost position in the body 12 . It will be observed that the upper end of the piston 14 is spaced from and clear of the probe 20 .
  • FIG. 1 b illustrates the relative positions of the tool elements when the flow-rate of the fluid flowing through the string has been reduced to a relatively low intermediate rate such that there is a minimal if any fluid pressure force created across the nozzle 16 and the upwards spring force on the piston 14 is greater than the opposing downwards forces; the piston 14 thus moves upwards under the influence of the spring 18 .
  • the piston 14 and probe 20 cooperate to create a rapid or step-change restriction in the fluid flow area, the pressure drop resulting from the flow restriction creating a fluid pressure force which maintains the piston 14 in the illustrated intermediate position.
  • the piston 14 will remain in this intermediate position until the flow-rate is increased to generate a sufficient fluid pressure force across the nozzle 16 to overcome the action of the spring 18 and move the piston 14 downwards towards the operating position as illustrated in FIG. 1 a , or until the flow-rate is reduced to a negligible level and the piston 14 translates upwards towards the no-flow configuration as illustrated in FIG. 1 c.
  • the configuration of the tool 10 is such that the operator may hold or retain the piston 14 in the intermediate position over a range of flow-rates, and it is not necessary for the operator to achieve a precise flow-rate to cause the piston 14 to hover in the intermediate position, as would be the case in the absence of the interaction between the piston 14 and the probe 20 ; the step-change in flow area created as the piston 14 and probe 20 move from the intermediate configuration towards the no-flow configuration tends to retain the intermediate configuration over a wider range of flow-rates.
  • the piston 14 moves upwards such that the probe 20 extends into and through the piston nozzle 16 .
  • the operator initiates flow through the string, typically by activating the surface pumps.
  • the intermediate configuration is likely to be achieved simply by turning the pumps up sufficiently to circulate fluid through the string; the occlusion of the tool 10 by the interaction of the piston 14 and the probe 20 causes the piston 14 to move beyond the end of the probe 20 and thus permit a degree of fluid flow.
  • the tool 10 may experience a degree of chatter, as the piston 14 moves between a just-open and just-closed position, however this may be avoided by a small increase in flow-rate.
  • FIGS. 2 a , 2 b and 2 c of the drawings are schematic illustrations of a tool 110 in accordance with a second embodiment of the present invention.
  • the tool 110 operates in a generally similar manner to the tool 10 described above, but includes a number of different features, as will be described.
  • the tool 110 includes a cylindrical body 112 and mounted within the body 112 is a tubular piston 114 having a cylindrical inner flow surface 115 .
  • a stepped-profile cylindrical flow probe 120 is mounted to the body 112 and, with the tool 110 in the no-flow configuration and the piston 114 in the raised position ( FIG. 2 c ), extends into the piston 114 .
  • the probe 120 is coaxial with the piston 114 and has an upper portion 120 a with an outer diameter only very slightly smaller than the internal diameter of the inner flow surface 115 and a lower portion 120 b at the probe free end with an outer diameter significantly smaller than the internal diameter of the surface 115 . Accordingly, while the probe upper portion 120 a is located within the piston 114 the tool body is substantially occluded, and while the probe lower portion 120 b is located within the piston 114 fluid may flow through the tool 110 .
  • FIG. 2 a illustrates the relative positions of the tool elements in a typical operating configuration, with fluid being pumped through the tool 110 and the associated string at a normal operational rate such as required during, for example, a drilling operation.
  • the fluid pressure differential created across the piston 114 and the restriction 130 a resulting from the interaction between the piston inner flow surface 115 and the probe lower portion 120 b is sufficient to move the piston 114 to its lowermost position in the body 112 , and fully compress the spring 118 .
  • the upper end of the piston 114 is spaced from and clear of the probe upper portion 120 a.
  • FIG. 2 b illustrates the relative positions of the tool elements when the flow-rate of the fluid flowing through the string has been reduced to a relatively low level such that there is a minimal fluid pressure force created across the restriction 130 a .
  • the upwards spring force on the piston 114 is thus greater than the opposing downwards forces and the piston 114 moves upwards under the influence of the spring 118 .
  • the piston 114 and probe transition 120 c cooperate to create a rapid or step-change restriction in the fluid flow area, the pressure drop resulting from the resulting restriction 130 b creating a fluid pressure force which maintains the piston 114 in the illustrated intermediate position.
  • the piston 114 will remain in this intermediate position until the flow-rate is increased to generate a sufficient fluid pressure force across the restriction 130 b to overcome the action of the spring 118 and move the piston 114 downwards, or until the flow-rate is reduced to a negligible level and the piston 114 translates upwards towards the no-flow configuration as illustrated in FIG. 2 c.
  • the configuration of the tool 110 is such that the operator may retain the piston 114 in the intermediate position over a range of flow-rates, and it is not necessary for the operator to achieve a precise flow-rate to cause the piston 114 to hover in the intermediate position, as would be the case in the absence of the interaction between the piston 114 and the probe transition 120 c ; the step-change in flow area created as the piston 114 and probe 120 move from the intermediate configuration tends to retain the configuration over a wider range of flow-rates.
  • the piston 114 moves upwards such that the entire probe 120 extends into the piston 114 and the upper probe portion 120 a substantially occludes the piston 114 .
  • the operator initiates flow through the string, typically by activating the surface pumps.
  • the intermediate configuration is likely to be achieved simply by turning the pumps up sufficiently to circulate fluid through the string; the occlusion of the tool 110 by the interaction of the piston 114 and the probe upper portion 120 a causes the piston 114 to move beyond the end of the probe transition 120 c in the presence of a relatively low flow rate.
  • the upper end of the probe 120 includes a wireline overshot profile 132 and a probe-mounting spider 134 which secures the probe 120 to the body 112 via shear pins 136 , thus permitting removal of the probe 120 from the tool 110 if desired. Retrieval of the probe 120 removes the bore restriction created by the probe 120 and also provides unrestricted access to the string bore below the tool 110 .
  • FIG. 3 of the drawings is a schematic illustration of a cam track 50 of a tool, such as one of the tools 10 , 110 as described above, in accordance with an embodiment of the present invention. As will be described, this embodiment permits an operator to configure the tool in two distinct operating configurations.
  • the cam track 50 is formed on the inner diameter of the tool body 12 , and a cam follower pin 52 extends radially outwards from the piston 14 .
  • the piston 14 In normal flow conditions the piston 14 is urged downwards with the interaction of the pin 52 and track 50 holding the piston 14 in a first position 1 corresponding to a first operating configuration, for example as illustrated in FIG. 1 a . If the fluid flow is then reduced to the intermediate flow-rate the pin 52 moves up the track 50 to a second position 2 , corresponding to the intermediate configuration, as illustrated in FIG. 1 b of the drawings. If the flow is held at the intermediate flow-rate for a short period, given the manner in which the piston 14 and probe 20 interact, the operator can be confident that the intermediate configuration has been achieved.
  • the pin 52 will travel back down the track 50 but will move into a blind track branch 50 a and to a third position 3 , which permits the piston 14 to be translated further downwards to a second operating configuration, as illustrated in FIG. 1 d of the drawings.
  • This extra stroke may be utilized to perform a desired tool activation, for example to actuate or extend a cutting blade on a reaming tool.
  • the pin 52 will move directly from position 1 to a fourth position 4 , corresponding to the no-flow configuration, as illustrated in FIG. 1 c . If the pumps are then restarted the pin 52 will move to the next position 1 , corresponding to the first operating configuration. Accordingly, if the pumps are stopped, for example to make a connection at surface, and then restarted, the tool 10 will not be activated. If activation is required the flow-rate must be reduced to and preferably held at the intermediate flow-rate and then increased again without stopping the pumps.
  • FIGS. 4 a , 4 b and 4 c of the drawings schematic illustrations of a tool 210 in accordance with another embodiment of the present invention.
  • the tool 210 operates in a manner which is generally similar to the tools 10 , 110 described above but has some different constructional features, as will be described.
  • a tubular piston 214 including an internal nozzle 216 , such that flow of fluid through the tool in the normal direction, that is from surface towards the distal end of the drill string incorporating the tool 210 , creates a fluid pressure force across the piston 214 , over seal area at seal diameter B, tending to translate the piston downwards, against the action of a compression spring 218 .
  • a cylindrical probe 220 is mounted on the upper end of the piston and cooperates with a restriction 215 provided in the body 212 above the piston 214 . With the piston 214 in the raised position ( FIG. 4 c ), the probe 220 extends into the restriction 215 .
  • the probe 220 has an outer diameter only slightly smaller than the internal diameter of the restriction 215 . Accordingly, while the probe 220 is located within the restriction 215 the tool body is substantially occluded.
  • FIG. 4 a illustrates the relative positions of the tool elements in a typical operating or drilling configuration, with fluid being pumped through the tool 210 at a normal operational rate, for example while drilling.
  • the fluid pressure differential created across the nozzle 216 is sufficient to move the piston 214 to its lowermost position in the body 212 in which the lower end of the body restriction 215 is spaced from and clear of the upper end of the piston probe 220 .
  • the relatively large seal area at least diameter B minimized the pressure drop required across the nozzle 216 , thus minimizing the pump pressure required to maintain the piston in the operating or drilling position.
  • FIG. 4 b illustrates the relative positions of the tool elements when the flow-rate of the fluid flowing through the string has been reduced to a relatively low, intermediate rate such that there is minimal if any fluid pressure force created across the nozzle 216 and the upwards spring force on the piston 214 is greater than the opposing downwards forces; the piston 214 thus moves upwards under the influence of the spring 218 .
  • the probe 220 and the restriction 215 cooperate to create a rapid or step-change restriction in the fluid flow area.
  • the fluid pressure force now acting over diameter A corresponding to the diameter of the probe 220 , maintains the piston 214 in the illustrated intermediate position.
  • the piston 214 will remain in this intermediate position until the flow-rate is increased to generate a sufficient fluid pressure force across the nozzle 216 to overcome the action of the spring 218 and move the piston 214 downwards towards the operating position as illustrated in FIG. 4 a , or until the flow-rate is reduced to a negligible level and the piston 214 translates upwards to the no-flow configuration as illustrated in FIG. 4 c.
  • FIG. 5 of the drawings illustrates a tool 310 in accordance with a further embodiment of the invention.
  • the tool 310 is illustrated in the intermediate or reduced flow position, with fluid pressure acting over area at seal diameter X [[A]], the area of the upper end of the piston probe 320 .
  • the tool 310 is similar to the tool 210 described above in a number of respects.
  • the piston 314 does not feature an internal nozzle. Rather, movement of the piston 314 to the operating position is achieved utilizing differential pressure, as described below.
  • the piston 314 carries external seals [[B]] 321 , [[C]] 322 which engage the inner wall of the body 312 , the volume between the seals [[B]] 321 , [[C]] 322 being in communication with the tool exterior.
  • a port to annulus 324 is provided in body 312 . Accordingly, in use, the volume will be in communication with the annulus.
  • the upper seals [[B]] 320 describe a larger diameter than the lower seals [[C]] 322 .

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  • 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)
  • Fluid-Pressure Circuits (AREA)
US14/182,132 2013-02-20 2014-02-17 Downhole tool control Abandoned US20140231096A1 (en)

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
GB1302981.4 2013-02-20
GB1302981.4A GB2511050A (en) 2013-02-20 2013-02-20 Downhole tool control

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US20140231096A1 true US20140231096A1 (en) 2014-08-21

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US14/182,132 Abandoned US20140231096A1 (en) 2013-02-20 2014-02-17 Downhole tool control

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CA (1) CA2843047A1 (fr)
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Cited By (2)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US20170260853A1 (en) * 2014-12-01 2017-09-14 Evolution Engineering Inc. Fluid pressure pulse generator for a downhole telemetry tool
US10400534B2 (en) * 2015-05-28 2019-09-03 Halliburton Energy Services, Inc. Viscous damping systems for hydrostatically set downhole tools

Citations (3)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US5141062A (en) * 1989-07-04 1992-08-25 Anderson Charles A Tool actuator
US5443128A (en) * 1992-12-14 1995-08-22 Institut Francais Du Petrole Device for remote actuating equipment comprising delay means
US20110083904A1 (en) * 2009-10-12 2011-04-14 Reddoch Sr Jeffrey A Short mud saver for use with top drive or kelly

Family Cites Families (2)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US7090020B2 (en) * 2002-10-30 2006-08-15 Schlumberger Technology Corp. Multi-cycle dump valve
GB0500713D0 (en) * 2005-01-14 2005-02-23 Andergauge Ltd Valve

Patent Citations (3)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US5141062A (en) * 1989-07-04 1992-08-25 Anderson Charles A Tool actuator
US5443128A (en) * 1992-12-14 1995-08-22 Institut Francais Du Petrole Device for remote actuating equipment comprising delay means
US20110083904A1 (en) * 2009-10-12 2011-04-14 Reddoch Sr Jeffrey A Short mud saver for use with top drive or kelly

Cited By (4)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US20170260853A1 (en) * 2014-12-01 2017-09-14 Evolution Engineering Inc. Fluid pressure pulse generator for a downhole telemetry tool
US10508538B2 (en) * 2014-12-01 2019-12-17 Evolution Engineering Inc. Fluid pressure pulse generator for a downhole telemetry tool
US10400534B2 (en) * 2015-05-28 2019-09-03 Halliburton Energy Services, Inc. Viscous damping systems for hydrostatically set downhole tools
US10900308B2 (en) 2015-05-28 2021-01-26 Halliburton Energy Services, Inc. Viscous damping systems for hydrostatically set downhole tools

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GB2511050A (en) 2014-08-27
GB201302981D0 (en) 2013-04-03

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