EP2955318A1 - Raccord à pivot de fond de trou et procédé pour libérer un objet coincé dans un puits de forage - Google Patents

Raccord à pivot de fond de trou et procédé pour libérer un objet coincé dans un puits de forage Download PDF

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Publication number
EP2955318A1
EP2955318A1 EP14171836.1A EP14171836A EP2955318A1 EP 2955318 A1 EP2955318 A1 EP 2955318A1 EP 14171836 A EP14171836 A EP 14171836A EP 2955318 A1 EP2955318 A1 EP 2955318A1
Authority
EP
European Patent Office
Prior art keywords
swivel
swivel part
shoulder
sub
workstring
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Withdrawn
Application number
EP14171836.1A
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German (de)
English (en)
Inventor
John Hanton
Jeffrey B. Lasater
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.)
Tercel IP Ltd
Original Assignee
Tercel IP 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 Tercel IP Ltd filed Critical Tercel IP Ltd
Priority to EP14171836.1A priority Critical patent/EP2955318A1/fr
Priority to GB1617582.0A priority patent/GB2542034B/en
Priority to PCT/EP2015/057040 priority patent/WO2015161993A2/fr
Priority to US15/306,548 priority patent/US10941620B2/en
Publication of EP2955318A1 publication Critical patent/EP2955318A1/fr
Withdrawn legal-status Critical Current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
    • 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
    • E21B17/05—Swivel joints

Definitions

  • the present invention is related to a downhole swivel sub suitable for connection in a workstring between an upper section hung out from the wellbore's surface and a bottom section in order to mitigate the drag by allowing the upper section of the workstring to rotate, the bottom section including a downhole element such as a jar, a vibration tool, a bottom hole assembly, a liner, a screen, a whipstock, a multilateral completion or any device which is not desirable or not possible to rotate into a wellbore.
  • the present invention is related to a method of operation in a wellbore using said swivel sub.
  • Drilling of a well for exploration or exploitation of an oilfield is performed by running a drillstring having a first tail end hung up and rotated at the surface of the well, and a front end comprising a bottom hole assembly run into the wellbore.
  • the bottom hole assembly comprises a drill bit for drilling a borehole
  • the drillstring comprises a bore extending from the tail end to the drill bit, in which is injected a drilling fluid from the top of well, allowing the evacuation of cuttings while drilling and providing cooling of the drill bit.
  • Rotation of the drillstring allows a better evacuation of the drilling mud and cuttings.
  • the bottom hole assembly generally comprises other devices such as stabilizers, mud motor, rotary steering systems, reaming tools, under reamers, or drilling collars.
  • rotation of the drill bit is performed thanks to a mud motor located near the drill bit.
  • Directional drilling is a process in which the orientation of the well may be deviated once or several times.
  • Introduction of the rotary steerable systems (RSS) technology has developed the use of directional drilling.
  • Directional drilling has allowed for example to skirt some zones of difficult-to-drill formations, to have access to some reservoirs inaccessible vertically, such as reservoirs located under a town or a lake or groundwater.
  • the wellbore may comprise some horizontal sections and more than one deviation from the top of the wellbore to the bottom of the wellbore. While drilling such a wellbore, some parts of the drill string may become stuck in the borehole, for example in case of collapsing of some parts of the borehole. Also, disconnection of one of the drill pipes of the drillstring or failure of a drill pipe can occur.
  • the drillstring comprises disconnection means that can be activated for allowing disconnection of some sections of the drillstring, for example for disconnecting a free section of the drillstring from a stuck section of the drillstring located downwards the free section.
  • a fishing assembly generally comprises a fishing tool at the front end of a string, and usually a jar located upstream the fishing tool, generally nearby the fishing tool.
  • the fishing tool comprises a means for grabbing the stuck object.
  • a jar is used for increasing the effect of a tensile or compressive force applied from the top of the string to free the object from the wellbore when the object is grabbed by said means for retrieving the object.
  • the fishing assembly is moved down until the fishing tool reaches the object stuck in the wellbore. Once the object is grabbed by the fishing tool, the drilling operator applies a tensile or compressive force from the top of the wellbore for pulling or pushing the stuck object, said longitudinal force activating the jar that provides a sudden variation of force on the stuck object that helps to attempt the releasing of the stuck object.
  • the jar generally comprises two telescoping parts and a mechanism that upon applying a tensile or compressive force to the workstring, first provides a hard resistance against upward or downward movement of the workstring, and thereafter suddenly provides a low resistance against such movement until the two telescoping parts collide against each other, providing an impact on the workstring that helps to release the stuck portion of the drillstring.
  • the drillstring comprises a drilling jar.
  • a drilling jar is a jar included in a drillstring.
  • a tensile or compressive force is applied from the surface of the well on the drillstring in order to try to free the stuck section of the drillstring.
  • a vibration tool such as disclosed in the US patent number 8439133 can be used to generate a pulsing action which is transmitted to a drill bit to avoid the drill bit becoming stuck or to free a stuck drill bit.
  • the stuck section of the drillstring is at a distance of a few kilometers from the surface of the well, the tensile force required to be applied on the drillstring for moving up the drillstring and firing the jar is elevated.
  • a vibration tool is used for freeing the stuck section of the string, it is suitable to apply a tensile force to increase the chances to free the stuck section.
  • the friction forces between the drillstring and the wall of the wellbore, more particularly in a highly deviated wellbore makes it almost impossible to fire the jar or to apply the suitable force which combined with the vibration provided with the vibration tool would allow to free the stuck section of the string.
  • Document US6082457 discloses a method of operating a drill string.
  • the drill string comprises a drilling tool, a drilling jar, and a swivel sub located between an upper section of the drillstring and a lower section of the drillstring.
  • the overall concept is a pressure activated clutch, whereby a ball is dropped and seats within the tool, providing an increase of internal pressure which disengages a clutch.
  • the clutch rotationally ties the upper and lower ends of the tool together. So, once disengaged the upper and lower ends of the tool are free to rotate relatively.
  • the swivel sub can be selectively locked or unlocked such that when the swivel sub is locked and when the upper section of the drillstring is rotated, the swivel sub transfers the rotation of the upper drillstring to the lower drillstring.
  • the swivel sub is unlocked, the upper drillstring can be rotated relative to the lower drillstring.
  • the swivel sub is unlocked and a tensile or compressive force is applied on the upper drillstring while rotating the upper drillstring. Rotation of the drillstring reduces the friction forces between the drillstring and the walls of the borehole that allows the tensile or compressive force to fire the jar.
  • this clutch is represented as a castellated axially engaged tooth. In this configuration the shear on the tooth is very small, has a high stress concentration, and therefore such an embodiment wouldn't be strong enough to take the full torsional load of the drillstring during nominal operations.
  • the tensile force to apply on the drill string from the well surface to pull kilometers of drillstring pipes for firing the jar or the compressive force to apply on the drill string from the well surface to push kilometers of drillstring pipes for firing the jar in an attempt to release the stuck portion of the drillstring is very elevated.
  • the firing of a jar requires the application of a tensile or compressive load in a range generally comprised between 10,000 lb and 180,000lb depending on the type of the jar.
  • the swivel sub must be able to allow the rotation of the upper part of the drillstring upon application of such a high load.
  • this swivel sub should be robust enough to support a load for firing a jar to release a portion of a drillstring which is stuck in a deep area of an "extended reach drilled" wellbore.
  • a swivel sub which can be used in a workstring for running a downhole element such as a liner, a screen, a whipstock or any other object that is not desirable to rotate into a wellbore, the swivel sub which should be able to selectively transmit sufficient torque to the downhole element for orient it or for attempting to unstuck it.
  • the present invention relates to a downhole swivel sub destined to be included between two sections of a workstring, said swivel sub having a bore extending there through and comprising:
  • This feature allows a much greater shear area of engagement and thus spreads the shear load over a much larger area.
  • the said locking sleeve comprises a coupling subsection and the said first swivel part comprises a matching coupling subsection such that the locking sleeve is able to move axially along the said coupling subsection of the said first swivel part.
  • the coupling subsection of the first swivel part is longer than the coupling subsection of the locking sleeve.
  • the coupling subsections of the locking sleeve and of the first swivel part have matching polygonal cross-sections.
  • a section of the said first swivel part is inserted into a section of the said second swivel part, the said first rows of teeth of the said locking sleeve are provided on the external surface of the locking sleeve and the said second rows of teeth of the said second swivel part are provided on the inner surface of the said second swivel part.
  • a section of the said first swivel part is inserted into a section of the said second swivel part, the said first swivel part comprising a shoulder and the said second swivel part comprising two abutments on either side of the said shoulder, or inversely, the said second swivel part comprising a shoulder and the said first swivel part comprising two abutments on either side of the said shoulder, a set of tensile bearings being provided between the said shoulder and a first abutment situated upwards the said shoulder, and a set of compression bearings being provided between the said shoulder and a second abutment situated downwards the said shoulder.
  • the said compression bearings or the said tensile bearings or both compression bearings and tensile bearings may be maintained on their respective abutments by a high preload compression spring and at least one secondary abutment facing a portion of the said shoulder may be located on the swivel part comprising the said first and second abutments, the secondary abutment(s) being located at a distance from the said shoulder inferior to the width of one of the said bearings.
  • the said second swivel part forms a chamber comprising the said locking sleeve, said chamber being sealed to the outside of the swivel sub.
  • the said locking sleeve lies on a J-slot index mechanism and a spring maintained by a shoulder inside said second swivel part.
  • a section of the said first swivel part is inserted into a section of the said second swivel part and wherein the said first swivel part comprises an opening, the said opening being positioned such as to allow a flow of fluid to push the said locking sleeve upon an increase of internal pressure in the said bore.
  • the invention is equally related to a downhole swivel sub destined to be included between two sections of a workstring, said swivel sub having a bore extending there through and comprising:
  • the said compression bearings or the said tensile bearings or both compression bearings and tensile bearings may be maintained on their respective abutments by a high preload compression spring and at least a secondary abutment facing a portion of the said shoulder may be located on the swivel part comprising the said first and second abutments at a distance from the said shoulder inferior to the width of one of the said bearings.
  • the invention is equally related to a method for operating a jar to release an object stuck into a wellbore, the said jar being located in a workstring downstream a swivel sub according to the invention, the said workstring being connected to the said stuck object, the said method comprising the steps of :
  • the invention is further related to method for operating a vibration tool to release an object stuck into a wellbore, the said vibration tool being located in a workstring downstream a swivel sub according to the invention, the said workstring being connected to the said stuck object, the said method comprising the steps of:
  • the invention is further related to a method for running a liner or a screen or a whipstock or any downhole element that is not suitable to rotate in a wellbore, the method comprising the steps of :
  • the terms “front”, “down”, “lower”, “downstream” and “moving down” relative to the downhole assembly of the present invention and its components means “facing or moving in a direction away from an entry opening of the wellbore at the surface.
  • the terms “tail”, “upstream”, “moving up”, “upper” and “up” relative to the downhole assembly of the present invention and its components means “facing towards or moving in a direction towards the entry opening of the wellbore”.
  • workstring means a string made of plurality of pipes connected to each other in order to run a downhole tool into a wellbore for drilling, for fishing or for doing any operation in the steps of the construction and operation of a wellbore.
  • the present invention relates to a swivel sub 100 suitable for connection in a workstring between an upper section hung out from the wellbore's surface and a bottom section in order to mitigate the drag by allowing the upper section of the workstring to rotate, the bottom section including a downhole element such as a jar, a vibration tool, a bottom hole assembly, a liner, a screen, a whipstock, a multilateral completion or any device which is not desirable or not possible to rotate into a wellbore.
  • a downhole element such as a jar, a vibration tool, a bottom hole assembly, a liner, a screen, a whipstock, a multilateral completion or any device which is not desirable or not possible to rotate into a wellbore.
  • the figure 1 shows a swivel sub 100 according to a preferred embodiment of the present invention comprising:
  • the housing assembly 104 comprises:
  • the mandrel 103 extends from the top end 109 of the first housing part through the housing assembly 104 until a section of the fourth housing part 104d.
  • the mandrel 103 comprises a bore 126 extending there through.
  • the figure 2 shows a view of the mandrel 103 according to a longitudinal cross section.
  • the mandrel 103 comprises:
  • the second mandrel part 103b comprises:
  • the first section 103b' of the second mandrel part 103b forms a shoulder 124 with the second section 103b" of the second mandrel part 103b.
  • An opening 123 is located next to the shoulder 124 on the outermost surface of the second section 103b" of the second mandrel part and extends from the external surface of the second section 103b" to the bore 126 of the mandrel 103.
  • the first section 103b' of the second mandrel part 103b further comprises a coupling subsection 120 arranged inside the third housing part 104c and having a coupling means, for example a set of teeth, but preferably a polygonal cross section.
  • the figure 3 shows an enlarged view of the first housing part 104a and the upper part of the mandrel 103.
  • the inner wall of the first housing part 104a comprises a first shoulder 107 and the outer surface of the first section 103b' of the second mandrel part 103b comprises a second shoulder 108, for example a collar fastened around the mandrel, arranged downwards relative to the first shoulder 107 and inside the first housing part 104a.
  • a set of tensile bearings 105 is arranged between the first shoulder 107 and the second shoulder 108.
  • the bottom end 110 of the first housing part 104a is a female end in which is screwed the top end 111 of the second housing part 104b.
  • the top end of the second housing part is configured to form a ledge 111 into the first housing part 104a.
  • a set of compression bearings 106 is arranged between the second shoulder 108 and the ledge 111 of the second housing part 104b.
  • both bearings are thrust bearings supporting an axial load.
  • a compression bearing is in compression when the entire tool is in compression and a tension bearing is in compression when the entire tool is in tension.
  • the said compression bearings 106 or the said tensile bearings 105 or both compression bearings and tensile bearings are maintained on their respective abutments 302, 301 formed by the first shoulder 107 and the ledge 111 respectively by a high preload compression spring 305.
  • At least one secondary abutment 303, 304 facing a portion of the said second shoulder 108 is located on the swivel part 104 comprising the said first and second abutments 301, 302, said secondary abutment(s) 303,304 being located at a distance from the said second shoulder 108 inferior to the width of one of the said bearings.
  • Such feature is beneficial while the swivel sub is used in a method for operating a jar or a vibration tool wherein the bearings are subject to high shocks. This feature prevents extreme shocks on the bearing when the jar fires, the greater load would then compress the springs, but before the springs bottom out, there are an abutment 303/304 and a shoulder 108 coming into contact preventing the extreme shock load from passing through the bearings.
  • the second shoulder 108 could be integral with the housing 104 instead of with the mandrel 103, in which case the first and second abutment 301,302 are situated on the mandrel 103 and not on the housing 104.
  • the secondary abutments 303,304 could be situated on the mandrel 103 instead of on the housing 104.
  • a pressure compensating piston 122 is provided around the mandrel 103, inside the first housing part 104a, between the top end 109 of the first housing part and the shoulder 107 of the first housing part such as to form a pressurized chamber.
  • the space between the first section 103b' of the second mandrel part 103b and the housing assembly is filled with a lubricant, facilitating the rotation and the movement of the pieces inside the housing assembly.
  • the figure 4 shows an enlarged view of the third housing part 104c according to a longitudinal cross section.
  • the top end 113 and the bottom end 114 of the third housing part 104c are provided by female thread sections which are screwed respectively to the male bottom section 112 of the second housing part 104b and to the male top section 115 of the fourth housing part 104d.
  • the inner diameter of the third housing part 104c relative to the external diameter of the second mandrel part 103b is set up such that a space is available between the mandrel 103 and the third housing part 104c for a locking sleeve 117, a J-slot index mechanism 118 and a spring 119.
  • the inner wall of the third housing part 104c comprises a first section provided with a set of teeth 116 which are offset from the coupling subsection 120 of the mandrel 103.
  • a locking sleeve 117 is arranged inside the third housing part 104c and around the mandrel 103.
  • the locking sleeve 117 comprises:
  • the figure 5a shows a transversal cross section view of the swivel sub 100 at the arrow A-A of figure 4 , wherein the teeth 116' of the locking sleeve 117 are engaged with the teeth 116 of the third housing part 104c.
  • the figure 5b shows a transversal cross section view of the swivel sub 100 at the arrow B-B of figure 4 , wherein the polygonal coupling subsection 120 of the mandrel 103 is coupled with the polygonal coupling section 121 of the locking sleeve.
  • the set of teeth 116 of the inner surface of the third housing part 104c comprises a plurality of rows of teeth, the teeth of each row being distributed radially inside the third housing part 104c.
  • the plurality of rows are aligned axially (i.e. corresponding teeth of all the rows are at the same radial position) and separated from each other in the axial direction by a distance slightly superior to the length of the teeth 116' of the locking sleeve.
  • the set of teeth 116' of the locking sleeve comprises a plurality of rows of teeth, the teeth of each row being distributed radially about the external surface of the locking sleeve 117.
  • the plurality of rows are aligned axially (i.e.
  • the length of the teeth 116 of the third housing part 104c are substantially the same than the length of the teeth 116' of the locking sleeve 117.
  • the distances separating each row of teeth 116 of the third housing part 104c are substantially the same as the distances separating each row of teeth 116' of the locking sleeve 117.
  • Such an arrangement of teeth 116, 116' allows transmission of an elevated torque from the mandrel 103 to the housing assembly 104, when the locking sleeve is in the locking position.
  • the transmission of torque from the first swivel part 103 to the second swivel part 104 is distributed across a section which is long enough for reducing the fatigue on the locking sleeve, on the mandrel and on the housing.
  • the figures 1 and 4 present a cross sectional view of the swivel sub along a longitudinal axis Z, wherein the section of the swivel sub above the Z axis is represented in the locking position and the section of the swivel sub under the Z axis is represented in the unlocking position.
  • the locking sleeve 117 is maintained by a spring 119, preferably by a set of Belleville springs 119 in a locking position locking the rotation of the mandrel 103 with the housing assembly 104.
  • the locking sleeve 117 is movable to the unlocking position as represented in the figures 1 and 4 under the longitudinal axis Z, wherein the rotation of the mandrel 103 is unlocked from the housing assembly 104, which allows free rotation of the mandrel 103 relative to the housing assembly 104.
  • the locking sleeve 117 is dimensioned so as to tightly contact the first section 103b' and the second section 103b" of the second mandrel part 103 and such that:
  • the opening 123 on the mandrel next to the shoulder 124 formed by the first section 103b' and the second section 103b" of the second mandrel part 103b allows the passage of a fluid that pushes down the locking sleeve 117 upon an increase of pressure into the bore 126 of the mandrel.
  • the locking sleeve 117 lies on a J-slot index sleeve 118 lying on the spring 119 or on the set of Belleville springs 119.
  • the third housing part 104c further comprises a pin 127 guiding the J-slot index sleeve 118.
  • the top end 115 of the fourth housing part 104d is screwed in the female bottom end 114 of the third housing part 104c and forms a ledge 115 in the third housing part 104c, on which ledge 115 lies the spring or the set of Belleville springs.
  • the swivel sub 100 of the invention is provided with the compression bearing 106 and tensile bearing 105 as described above, but wherein the coupling between the mandrel and the locking sleeve is configured in a manner that is known per se in the art, such as by a classic spline-type coupling.
  • the additional shoulders 303,304 are provided with respect to the shoulder 108, in the manner as described above.
  • the invention is equally related to a swivel sub as described in any of the embodiments described above, but wherein the locking sleeve 117 is rotationally coupled to the housing 104 instead of to the mandrel.
  • the teeth 116 are located on an outer surface of the mandrel, while the teeth 116 are on an inner surface of the locking sleeve 117. All other details described in relation to the embodiments shown in the drawings are applicable mutatis mutandis.
  • Figure 6a presents an arrangement of a workstring section including subsequently a swivel sub 100 according to the present invention, a dart (or ball) catcher sub 200, a jar 300 and a bottom hole assembly 400 comprising preferably a drilling tool 500.
  • Figure 6b shows a second embodiment of an arrangement of a workstring section including subsequently a swivel sub 100 according to the present invention, a jar 300, a dart (or ball) catcher sub 200 and a bottom hole assembly (BHA) 400 comprising preferably a drilling tool 500.
  • BHA bottom hole assembly
  • the dart (or ball) catcher sub 200 is a separate sub located downstream to the swivel sub 100.
  • the dart/ball catcher sub 200 comprises a bore extending there through and in which is provided a dart/ball catcher assembly that catches a dropped dart.
  • Such devices are common in the art.
  • the dart When the dart is caught by the dart catcher assembly, it causes a pressure differential across the dart, which causes an increase of the pressure of the drilling fluid flowing through the work string and allows the drilling fluid to flow through the opening 123 for pushing down the locking sleeve 117 and the J-slot indexing sleeve 118 towards the unlocking position decoupling the set of teeth 116' of the locking sleeve from the set of teeth 116 of the third housing part 104c.
  • the pressure flow of the drilling fluid can be reduced while the locking sleeve is kept in its unlocking position allowing the mandrel 103 to be rotated with respect to the housing assembly 104.
  • the upper part of the drill string connected to the mandrel 103 of the swivel sub is rotated relative to the housing assembly 104 and the lower part of the drill string connected to the housing assembly 104.
  • Rotation of the upper part of the drill string reduces the drag between the upper part of the drill string and the walls of the wellbore, and allows more force to be transmitted to the Bottom Hole Assembly (BHA) which could free a stuck BHA 400 or facilitate the functioning of drilling jars 300 either up or down.
  • BHA Bottom Hole Assembly
  • the swivel sub 100 can be relocked when the BHA is freed, providing full string integrity back to the BHA to continue drilling operations. Relocking of the swivel sub can be performed by increasing once again the pressure of the drilling fluid for allowing to the drilling fluid to flow through the opening 123 for pushing down the locking sleeve 117 and the J-slot indexing sleeve 118 such that the J-Slot indexing sleeve compresses the spring or the Belleville springs. Then the fluid pressure is decreased for releasing the pressure on the spring or the Belleville springs which release its energy on the J-slot indexing sleeve pushing the locking sleeve back in its locking position.
  • the swivel sub 100 can be unlocked again and rotated or back reamed through any obstruction.
  • the swivel sub 100 allows to aid the operation of drilling jars in Horizontal and ERD wells, by allowing free rotation of the drillstring, independent of the BHA, thus reducing friction and allowing the operator to get more tensile and compressive force to activate the jar.
  • the swivel sub 100 is simple to operate with a series of pump dropped darts that get caught in a dart catcher assembly provided in a dart catcher sub 200 downstream the swivel sub 100.
  • the tool according to the invention it is presumed to use a dart and a dart catcher, however that device is below the tool and somewhat independent from the mechanism. So we can use a ball, a dart, or simply pressure against the formation if flow is inhibited. Further, the dart envisaged is similar to a multi-dart system whereby the dart has an integral rupture disk. Once dropped, an over pressure causes the disk to rupture, thus allowing flow. Then another dart can be dropped, which seats into the previous dart.
  • dart catcher or other ball catching device which is located immediately below the tool. Also not shown is the jarring mechanism - most likely somewhere below the tool.
  • the swivel sub 100 is a multi-cycle tool that will allow the operator to continue drilling ahead after freeing the stuck BHA with no reduction in the drilling capabilities or swivel sub specification after re-locking.
  • the swivel sub 100 can also be used to run heavy long liners, screens and other open-hole completions.
  • the swivel sub 100 can be used to mitigate drag and provide additional force when used on high angle fishing operations.
  • the swivel sub 100 allows the drillstring to continue to be rotated when a BHA becomes stuck, maintaining suspension of cuttings, reducing the risk of the drillstring from becoming stuck in addition to the BHA.
  • the use of the swivel sub according to the present invention in a drillstring reduces the recover cost of a stuck in hole incident.

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  • Engineering & Computer Science (AREA)
  • Life Sciences & Earth Sciences (AREA)
  • Geology (AREA)
  • Mining & Mineral Resources (AREA)
  • Mechanical Engineering (AREA)
  • Physics & Mathematics (AREA)
  • Environmental & Geological Engineering (AREA)
  • Fluid Mechanics (AREA)
  • General Life Sciences & Earth Sciences (AREA)
  • Geochemistry & Mineralogy (AREA)
  • Earth Drilling (AREA)
EP14171836.1A 2014-04-25 2014-06-10 Raccord à pivot de fond de trou et procédé pour libérer un objet coincé dans un puits de forage Withdrawn EP2955318A1 (fr)

Priority Applications (4)

Application Number Priority Date Filing Date Title
EP14171836.1A EP2955318A1 (fr) 2014-06-10 2014-06-10 Raccord à pivot de fond de trou et procédé pour libérer un objet coincé dans un puits de forage
GB1617582.0A GB2542034B (en) 2014-04-25 2015-03-31 Downhole swivel sub and method for releasing a stuck object in a wellbore
PCT/EP2015/057040 WO2015161993A2 (fr) 2014-04-25 2015-03-31 Raccord orientable de fond de trou et procédé de libération d'un objet coincé dans un trou de forage
US15/306,548 US10941620B2 (en) 2014-04-25 2015-03-31 Downhole swivel sub and method for releasing a stuck object in a wellbore

Applications Claiming Priority (1)

Application Number Priority Date Filing Date Title
EP14171836.1A EP2955318A1 (fr) 2014-06-10 2014-06-10 Raccord à pivot de fond de trou et procédé pour libérer un objet coincé dans un puits de forage

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EP2955318A1 true EP2955318A1 (fr) 2015-12-16

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Cited By (2)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
CN115584943A (zh) * 2022-10-28 2023-01-10 西南石油大学 一种可丢手卡扣式井下投捞工具
CN115929236A (zh) * 2023-01-05 2023-04-07 成都理工大学 水平定向钻进绳索取心管液囊式智能快速投放装置

Citations (6)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US6082457A (en) 1997-02-25 2000-07-04 Shell Oil Company Method of using a drill string tool
US6244345B1 (en) * 1996-12-31 2001-06-12 Specialty Rental Tool & Supply Co., Inc. Lockable swivel apparatus and method
US20030127857A1 (en) * 2000-02-04 2003-07-10 Boyd's Bit Service, Inc. Manually actuated mechanical locking swivel
US20040094309A1 (en) * 2002-11-14 2004-05-20 Maguire Patrick G. Hydraulically activated swivel for running expandable components with tailpipe
US20120234559A1 (en) * 2005-04-15 2012-09-20 Tercel Oilfield Products Uk Limited Downhole swivel sub
US8439133B2 (en) 2010-01-11 2013-05-14 Nighthawk Energy Services Canada Ltd. Down hole apparatus for generating a pusling action

Patent Citations (6)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US6244345B1 (en) * 1996-12-31 2001-06-12 Specialty Rental Tool & Supply Co., Inc. Lockable swivel apparatus and method
US6082457A (en) 1997-02-25 2000-07-04 Shell Oil Company Method of using a drill string tool
US20030127857A1 (en) * 2000-02-04 2003-07-10 Boyd's Bit Service, Inc. Manually actuated mechanical locking swivel
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CN115584943A (zh) * 2022-10-28 2023-01-10 西南石油大学 一种可丢手卡扣式井下投捞工具
CN115584943B (zh) * 2022-10-28 2024-04-16 西南石油大学 一种可丢手卡扣式井下投捞工具
CN115929236A (zh) * 2023-01-05 2023-04-07 成都理工大学 水平定向钻进绳索取心管液囊式智能快速投放装置
CN115929236B (zh) * 2023-01-05 2024-04-12 成都理工大学 水平定向钻进绳索取心管液囊式智能快速投放装置

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