WO1986003544A2 - Appareil pour mettre en place et retirer des dispositifs de commande de l'ecoulement dans les puits - Google Patents

Appareil pour mettre en place et retirer des dispositifs de commande de l'ecoulement dans les puits Download PDF

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Publication number
WO1986003544A2
WO1986003544A2 PCT/US1985/002411 US8502411W WO8603544A2 WO 1986003544 A2 WO1986003544 A2 WO 1986003544A2 US 8502411 W US8502411 W US 8502411W WO 8603544 A2 WO8603544 A2 WO 8603544A2
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WO
WIPO (PCT)
Prior art keywords
mandrel
bore
section
side pocket
further characterized
Prior art date
Application number
PCT/US1985/002411
Other languages
English (en)
Other versions
WO1986003544A3 (fr
Inventor
Douglass W. Crawford
William B. Crawford
Robert W. Dinning
Original Assignee
Crawford Douglass W
Crawford William B
Dinning Robert W
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
Priority claimed from US06/679,263 external-priority patent/US4765403A/en
Priority claimed from US06/789,313 external-priority patent/US4715441A/en
Application filed by Crawford Douglass W, Crawford William B, Dinning Robert W filed Critical Crawford Douglass W
Priority to DE8686900445T priority Critical patent/DE3579457D1/de
Publication of WO1986003544A2 publication Critical patent/WO1986003544A2/fr
Publication of WO1986003544A3 publication Critical patent/WO1986003544A3/fr

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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
    • E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
    • E21B43/12—Methods or apparatus for controlling the flow of the obtained fluid to or in wells
    • E21B43/121—Lifting well fluids
    • E21B43/122—Gas lift
    • E21B43/123—Gas lift valves
    • 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
    • E21B23/03—Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells for setting the tools into, or removing the tools from, laterally offset landing nipples or pockets

Definitions

  • the present invention relates generally to side pocket mandrel and kick-over tool apparatus for placing 5 and removing well flow control devices such as gas lift valves, and particularly to a new and improved kickover tool having an inwardly biased arm so as to be less likely to hang up while running a flow control device into a well tubing.
  • the present invention also provides a new and 0 improved side pocket mandrel having a unique valve-receiv ⁇ ing seat that is constructed and arranged such that removal of a flow control device is more easily and reliably accomplished without damage thereto as compared to prior art devices. 5
  • Wells having a production string of tubing that includes vertically spaced side pocket mandrels arranged 0 for placing, retrieving and manipulating flow control devices such as gas lift valves, are used extensively in gas and oil well production operations.
  • Each of the mandrels generally includes an open-topped side pocket that is laterally offset to the side of the mandrel bore. 5
  • a placement and removal tool known as a "kick-over" tool is lowered through the tubing to the level of the mandrel to effect placement or removal of a valve assembly in the side pocket.
  • the device can be a gas lift valve that includes a dome pressure operated regulator 0 valve, and which is held in the pocket by a latch assembly that engages a shoulder above the top of the pocket.
  • Prior side pocket mandrels generally have been constructed with a main bore 'that is aligned with the bore 5 of the well tubing and a side pocket that is laterally offset from the main bore. Examples of such devices are shown in United States Patent Nos. 2,824,525, 3,268,006, and 3,741,299.
  • the main bore of the mandrel allows various wire line tools to pass therethrough for the performance of well operations below the mandrel while a flow control device is positioned in the side pocket.
  • the side pocket typically has polish bores at the upper and lower ends thereof that are engaged by spaced packing rings in the flow control device, and a plurality of ports through the wall thereof to communicate gas from the well annulus to a valve element that controls the injection of the gas into the tubing string.
  • the mandrel assembly is made as a weldment of swedge nipples to the ends of a round or oval pipe sec ⁇ tion, which is a construction that is inherently weak and subject to corrosion at the weld points. Moreover, a weldment is more difficult to protect through use of an internal plastic coating.
  • Prior art mandrels also have been provided with deflector means for protecting flow control devices posi ⁇ tioned in the side pocket, and guide means for preventing tools moving through the well tubing from catching and hanging in the mandrel. Examples of such devices are disclosed in U.S. Patent Nos. 3,741,299, 3,802,503, 4,106,503, and 4,106,564.
  • the side pocket of the typical prior art mandrel generally is enclosed within the mandrel body, and thus the condition of the bore of the side pocket cannot be observed prior to running.
  • a worn-out or corroded bore in the side pocket may result in having to pull the entire string of well tubing - a very costly and time-consuming operation.
  • the machining of these mandrels has not allowed for precision' work in connection with the maintenance of close tolerances, or visual inspection which invaribly results in excessive manufacturing costs.
  • the flow control devices that are seated therein are in contact with noxious well fluids and subject to varying temperatures which require that the devices be designed to meet these conditions. This results in the use of expensive materials for construction of the flow control devices and the performance of tedious calcula ⁇ tions for temperature corrections.
  • the usual flow control device seats within a side pocket that is aligned parallel to the longitudinal axis of the main bore of the mandrel.
  • two sets of packing are used to seal the flow control device within the pocket, one near the top of the device and one near the bottom. Due to the parallel alignment of the flow control device relative to the main bore, and to the use of the two sets of packing, a removal tool has to make a long straight pull on the flow control device upwardly through the side pocket in order to remove the device from its seat.
  • the conventional removal tools inherently pull on the valve latch at an angle which places the latch and the flow control-device in a bind, thereby causing, in many instances, bent or broken flow control devices and latches. Such damage may result in a costly pulling job, and oftentimes may require the replacement of equipment.
  • a further disadvantage of prior structures is that the side pocket mandrels have required that retrievable- type flow control devices be utilized, negating the use of conventional type flow control devices within this type of equipment.
  • the kickover tools of the prior art are generally activated by pulling dogs on the tool up against a shoulder in the mandrel to release the kickover arm that caries the flow control device.
  • the arm is biased outwardly so that its outward movement aligns the bottom nose of the device with the side pocket of the mandrel. Downward movement and jarring are then used to insert the flow control device into the side pocket and to release the arm from the latch which engages underneath a shoulder to hold the device in the pocket. Since the kickover arm and flow control device are .normally biased outwardly, there is always a considerable risk of the tool being prematurely activated which can cause it to drag and hang up in the tubing.
  • Some of the latches included in the valve assemblies of the prior art are drilled through to permit the gas from the flow control device to enter into the main bore of the mandrel. Such construction limits the available gas flow area.
  • the general object of the present invention is to provide a new and improved side pocket mandrel, kickover tool, and combination of elements that alleviates most, if not all, of the foregoing disadvantages.
  • a side pocket mandrel having an open bore that is aligned with the bore of the tubing in which the mandrel is connected.
  • the mandrel has an enlarged body section with a cylindrical opening formed at the top thereof that is adapted to receive a flow control device such as a gas lift valve.
  • the opening is formed in a short-length seating section that is welded to the end of the central body section.
  • the longitudinal axis of the opening is slightly inclined with respect to the longitudinal axis of the open bore, and is arranged to interest the bore axis at a point below the opening.
  • the cylindrical opening is machined to receive and engage the packing near the latch end of the gas lift valve, and an inwardly directed shoulder is provided on the mandrel wall adjacent and below the opening to engage a latch assembly on the end of the valve and hold it in place with its opposite end protruding into the annulus between the tubing and the casing.
  • the opening is formed with a diameter that is substantially larger than the body of the flow control device that extends therethrough to facilitate removal of the device as will become more apparent herein. 44
  • a lower end portion of the side pocket mandrel of the present invention can be provided with generally longitudinally extending guide means on interior walls thereof which cooperate with instrumental- ities on the kickover tool to guide the flow control device into the cylindrical opening during upward movement of the kickover tool within the mandrel.
  • instrumental- ities on the kickover tool to guide the flow control device into the cylindrical opening during upward movement of the kickover tool within the mandrel.
  • Such instrumen ⁇ talities are normally retracted as the kickover tool is being run into the well, and are released to project outwardly and engage the guide means in response to manipulation of the kickover tool as will be subsequently described.
  • the mandrel has in its upper end section an orienting sleeve having oppositely disposed helical lower surfaces that lead to a longitudinally extending groove.
  • the kickover tool of the present invention includes an upper body that carries a pair of outwardly biased dogs or keys that are vertically spaced and are mounted for relative angular movement.
  • a tray connected to the lower end of the body has an inwardly biased pivot arm connected to its lower end, and the upper end of the arm is releas- ably coupled to the latch assembly of a flow control device so that the arm and device normally are positioned alongside the tray as the assembly is being run.
  • the pivot arm carries a pair of normally retracted elements, such as wings or rollers, that when extended on opposite sides of the arm can engage the guide means in the mandrel and cause the arm and flow control device to pivot outwardly into alignment with the cylindrical opening. The extension of these elements is under the control of a release rod which extends upwardly through the tray to the vicinity of the lower dog or key on the upper body.
  • the keys are rotated relative to one another to a misaligned position as the kickover tool is prepared for insertion into the tubing, and such misalignment causes the release rod, which is spring loaded, to function to retain the normally retracted elements on the pivot arm in their inner position.
  • the keys can pivot inwardly to pass through the orienting sleeves in the various side pocket mandrels that are above the mandrel in which the flow control device is to be placed.
  • the kickover tool reaches the target mandrel, it is lowered to a position just below this mandrel, and then is raised upwardly into it.
  • the upper one of the keys will find the slot in the orienting sleeve, and in so doing, rotationally orient the tool so that the pivot arm and flow control device are radially aligned with the side pocket.
  • the lower key engages one of the helical surfaces on the lower end of the orienting sleeve, it is forced to rotate into vertical alignment with upper key, which releases the control rod for downward movement under the influence of a coil compression spring.
  • Such downward movement causes or enables outward movement of the wings or rollers on the pivot arms, to positions where they engage the guide means in the lower portion of the mandrel during continued upward movement.
  • the flow control device is provided with a special sub between the body thereof' and the latch mechanism which has one or more gas flow ports that open laterally through the side of the body.
  • the ports are directed during assembly of the valve on the tool so that they point inwardly.
  • the sub also may be provided with a guard shoulder that will prevent placement of the valve unless the ports are properly directed.
  • the unique construction of the side pocket mandrel of the present invention obviated numerous disadvantages of the prior art structures.
  • the use of one packing and one seal or polish bore provides a simplified construc ⁇ tions which is much easier to release when it is desired to remove the value.
  • the flow control device protrudes into the annulus, as opposed to being confined within the mandrel body, which enables the side pocket mandrel to be constructed with a significantly shorter length, with consequent savings in material and manufacturing costs.
  • the inclination of the cylindrical opening with respect to central bore of the mandrel facilitates removal and place ⁇ ment of flow control devices because the direction of placement and removal forces is substantially aligned with the axis of the opening.
  • FIGs. 1 through 3 are schematic views of a wall installation that incorporates a side pocket mandrel in a tubing string, and showing the placement of a flow control device in the mandrel;
  • Figs. 4A and 4B are side sectional views of a side pocket mandrel constructed in accordance with the present invention.
  • Fig. 5 is a side section view of the control sleeve used in the mandrel of Figs. 4A and 4B;
  • Fig. 6 is a developed plan view of the sleeve shown in Fig. 5;
  • Fig. 7 is a developed view of an alternative embodi ⁇ ment of a control sleeve
  • Fig. 8 is a cross-sectional view taken on line 8-8 of Fig. 4A;
  • Figs. 9A and 9B are side elevational views, partly in cross-section, of one embodiment of the placement and removal tool of the present invention, succeeding figures being lower continuations of one another;
  • Fig. 10 is a cross-section on line 10-10 of Fig. 9A;
  • Fig. 11 is a longitudinal sectional view, with portions in side elevation, of the carrier sleeve of the placement and removal tool'; 3544
  • FIG. 12 is a side elevational view, partly in cross-section, of a pulling tool that can be used with the present invention
  • Figs. 13A and 13B are side elevational views, partly in cross-section, of a valve assembly and latch mechanism that can be set in the side pocket mandrel of the present invention
  • Figs. 14A and 14B are longitudinal sectional views showing the kickover tool as disclosed herein engaging a flow control device within the packing barrel of the side pocket mandrel;
  • Fig. 15 is a cross-section on line 15-15 of Fig. 13B;
  • Figs. 16A - 16C are longitudinal sectional views, with portions in side elevation, of another embodiment of the present invention.
  • Fig. 17 is a sectional view of the pivot arm assembly of Fig. 16;
  • Figs. 18-21 are cross-sections taken on lines 18-18, 19-19, 20-20, and 21-21 of Figs. 16A, 16B and 16C, respectively;
  • Fig. 22 is a fragmentary elevational view of the upper dog assembly on the orienting section
  • Figs. 23A and 23B are longitudinal sectional views of another embodiment of a side pocket mandrel in accordance with the present invention.
  • Figs. 24A and 24B are longitudinal sectional views of a side pocket mandrel that is constructed in accordance with this invention.
  • Fig. 25 is a three-dimensional view of the valve seating section of Fig. 24A;
  • Fig. 26 is a cross-section taken on line 26-26 of Figure 24A.
  • Figure 27 and 28 show modifications of the mandrel of the present invention.
  • the side pocket mandrel is designated generally by the numeral 10 and is connected in a well tubing 11 which leads upwardly to the surface.
  • the mandrels 10 located at vertically spaced points in the tubing 11, and of course the tubing is located inside of a well casing 15 which lines the well bore.
  • a packer anchors the lower end of the tubing 11 in the casing 15, and seals off the annulus 16 so that pressurized gas can be injected therein at the surface to effect gas lift operations.
  • the mandrel 10 as shown in these Figures for purposes of illustration and explanation, can be considered to be divided into three functional sections: an orienting section A, a main bore section B, and a side pocket section C.
  • the section B has an open bore 12, which is arranged in alignment with the bore of well tubing 11, and the mandrel includes a "mule shoe” or orienting sleeve 13 that preferably is integrally constructed within an annular recess disposed in the top of the mandrel.
  • the sleeve 13 also is positioned in alignment with the main bore section B.
  • the internal wall surface of the orienting sleeve 13 may be constructed to have the same diameter as the internal wall surface of the main bore section B.
  • a "kickover" tool indicated generally at 20 which carries a flow control device such as a gas lift valve 21 is shown being lowered into the tubing 11 on a wire line 22.
  • the gas lift valve 21 has a latch mechanism 23 on its lower end, and a latch sub 24 connects the mechanism 23 to the upper end of a kickover arm 25 which is pivotally connected to the body of the tool 20.
  • An orienting dog 26 is pivotally attached to the upper end section of the tool 20, and functions in connection with a longitudinally extending slot 28 in the sleeye 13 to rotationally orient the tool and valve within the side pocket mandrel such that the valve is disposed within the enlarged section C of the mandrel and below a valve seat 29 located at the upper end thereof.
  • the dog 26 functions in combination with another spring loaded dog, to be described below, and which engages in an oppositely disposed slot 37, to cause relative rotation of the dogs which result in a release of the kickover arm 25 so that the arm, sub 24 and valve 21 are kicked outward as shown in Fig. 2.
  • the tool can be raised by wire line manipulation at the surface to cause the valve 21 to be inserted through the opening 29 so that it projects into the annulus 16 between the tubing and the casing.
  • the valve 21 is automatically latched into the opening 29 by the mechanism 23, so that the arm 24 can be released therefrom by downward jarring and the kickover tool withdrawn from the well, leaving the gas lift valve in place.
  • the side pocket mandrel 10 has the orienting sleeve 13 fixed within its upper end section A.
  • a sleeve that can be used with the kickover tool described above is shown in enlarged detail in Figs. 5 and 6.
  • the sleeve 13 has helical surfaces 32 on its lower end which lead to a longitudinal slot 33.
  • the centerline of the longitudinal slot 33 is located 180° from the apex 34 of the helical surfaces 32.
  • Longitudinal slot 33 widens near its upper most end, such area being indicated by the numeral 35, where it defines an angular shoulder 36.
  • the orienting sleeve 13 also includes a cam locking slot 37, its centerline being vertically aligned with the apex 34 of the surfaces 32, thereby placing the centerline of cam locking slot 37 180° from the centerline of longitudinal slot 33.
  • FIG. 7 An alternative embodiment of an orienting sleeve is shown in Fig. 7. This particular embodiment is utilized with a kickover tool having a stationary dog 40 and a rotating dog 41 which initially are aligned on the same side of a kickover tool. In this case the lower helical surfaces 42 of the sleeve lead upwardly to a longitudinal
  • the mandrel 10 including the orienting section A, the body section B, and the side pocket section C may be integrally cast rather than being made from tubing that is welded together. This permits the walls of the side pocket 50 to be made thicker where they join the main bore section B. A cast construc ⁇ tion advantageously prevents metal fatigue and the inadvertent breaking of the side pocket section C.
  • the integrally cast construction also serves to prevent the formation of rust and corrosion.
  • the entire mandrel 10 may be cast as one unit, or the mandrel may be cast in upper and lower units which are then welded together. The upper unit would include the orienting section A, the upper end of the main bore section B, the valve seat 29, and the locking shoulder 51.
  • a stop groove 52 is included in the wall of the main bore section B of the mandrel 10 so as to facilitate retrieval of one embodiment of the kickover tool 20 as will be more fully described hereinafter.
  • the side pocket section C of the mandrel 10 includes a packing seat 29 for support of a flow control device 21.
  • the seat 29 is machined as a polish bore for receiving one set of packing 53 on the flow control device 21.
  • the polish bore 29 is open at both ends, and when the flow control device 21 is engaged therein the device extends into the annulus 16 between the well tubing 11 and the well casing 15.
  • the cylindrical bore 29 has its axis slightly inclined with -1 - respect to the longitudinal axis of the bore of the section B in the preferred embodiment of the present invention.
  • This inclination (about 1.5°) reduces the length of pull required to remove a flow control device 21, and therefore enables construction of the mandrel 10 such that the side pocket section C is shortened which thereby decreases the cost of construction of the mandrel.
  • the flow control device 21 can be inclined at a greater angle rela ⁇ tive to the longitudinal axis of the mandrel 10, because the outside diameter of the flow control device 21 is considerably smaller than the diameter of the seat 29.
  • the detent shoulder 51 is provided on the inside wall 50 of the side pocket below the lower end of the polish bore 29.
  • the shoulder 51 extends laterally and circumferentially around the inside wall 50 of the side pocket about 180° with respect to the polish bore, and serves as a stop for a tapered ring of the latch mechanism 23 when the valve has been inserted in the seat 29.
  • a kickover tool 20 generally includes an orientation assembly 60, a control assembly 61 and a kickover assembly 62.
  • the orientation assembly 60 includes three ⁇ ubassem- blies: a rotatable cam 26, a drive 64, and a clutch 65.
  • the orientation assembly 60 has a mandrel or body 66 -1 5- having a threaded fishing neck 67 attached to its upper end.
  • the body 66 is formed with a recess 70 that is generally rectangular, in shape and which is intersected by ' a vertical bore 71.
  • the cam 26 is mounted in the recess 70 on a pin 72, and is biased for clockwise rotation by a hinge spring 73.
  • the cam 26 has an outwardly projecting shoulder 74 and an inwardly facing stop surface 75 that engages the upper enlarged head 76 of a release rod 77.
  • the shoulder 74 extends beyond the outer periphery of the body 66 and functions to engage the helical lower surfaces 32 of the orienting sleeve 13 to thereby guide itself into the slot 33 and then into the recess 35.
  • the rod 77 has a hole through which a cross pin 78 extends, and the pin extends through an elongated slot 79 in the body 66 and into aligned apertures in a drive ring 80.
  • a compressed coil spring 81 encircles a reduced diameter section 82 of the body 66 and reacts between a downwardly facing shoulder on the body 66 and the upper end surface of the ring 80.
  • a plurality of ball detents 83 are held inwardly in engagement with an annular groove 84 on the body section 82 by the lower inner surface of a retainer cup 85 having an enlarged diameter release surface 86 near its upper end.
  • the retainer cup 85 is supported against downward movement on the body 66 by a release ball 87 which engages in a body groove 88 having an arcuate, horizontal section 89 and a vertical, downwardly extending section 90.
  • the groove 88 and release ball 87 are shown out of position in Fig.
  • a spring loaded dog 92 extends through a window 93 in the retainer cup 85 and is located opposite the release ball 87. Thus when the parts are assembled the dog 92 initially is located 180° out of alignment with he cam 26.
  • a control rod 94 has its threaded upper end screwed into a ring 95 that is located below the retainer cap 85. The rod 94 extends downwardly through a hole in the upper section of the kickover tool tray 20. When the tool is being run into the tubing 11 on wireline, the retainer cap 85 and the control rod 94 are in the upper position shown in Fig. 9A.
  • the retainer cup 85 is released in the following manner.
  • the cam dog 74 will encounter the lower surfaces 32 of the orienting sleeve 13.
  • the cam dog is forced'to rotate into alignment with the slot 33, which orient the tool such that the flow control device is aligned with the cylindri- cal seat 29 in the mandrel 10.
  • the spring loaded dog 92 is forced inwardly and then snaps into engagement with the vertical slot 37.
  • the cam dog 26 encounters the inclined shoulder 36, the body 66 is rotated relative to the retainer cup 85, which held by the dog 92, to bring the ball 87 into align ⁇ ment with the ball groove 90.
  • the tray 20 can have a longi ⁇ tudinal groove 100 formed on its rear side which receives the control rod 94, and a guide lug 102 having an opening through which the lower end of the rod extends.
  • the lower end of the rod 94 is attached to a block 103 by a threaded pin 104, and the block projects outwardly somewhat as shown.
  • a carrier tube 105 (Fig. 9B) is slidably mounted on the lower portion of the tray 20, and is provided with a plurality of upwardly extending collet fingers 106 having head portions 107.
  • the head portion 107 that is disposed in alignment with the block 103 is provided with a stop shoulder member 108 on the inner surface thereof.
  • the shoulder member 108 is spaced a certain distance above the lower surface 109 of the slot 100.
  • the lower end section 112 of the tray 29 is slidably fitted within the carrier sleeve 105.
  • a transverse pin 113 that extends through a slot 114 in the end section 112 has its ends fitted in diametri- cally opposed apertures in the carrier sleeve 105 so as to move therewith.
  • the kickover arm 25 has its lower end pivoted to the tray 20 by a pin 116, and its upper end pivoted to the latch arm 24 by a pin 117.
  • a coil spring 118 having its outer end bearing against the inner wall of the carrier sleeve 105 pushes against a wall surface 119 of the pivot arm 24 at a point below the pin 116 so as to tend to pivot the upper end of the arm outwardly.
  • a catch shoulder 120 on the lower end of the arm 24 is engaged by the transverse pin 113 in order to prevent pivotal rotation of the arm.
  • the carrier sleeve 105 -18- must be moved downwardly somewhat relative to the bottom section 112 of the tray 20 in order to disengage the pin 113 from the catch shoulder 120.
  • Another coil spring 122 reacts between a tang 123 on the upper end of the pivot arm 24 and an outwardly facing surface 124 on the latch arm 24 above the pivot pin 117.
  • the latch arm 24 is urged to pivot in a counter clockwise direction about the pin 117 when the arms are retracted.
  • the lower end of the arm 24 has an inwardly facing surface that engages a companion surface on the upper end of the arm 25 to limit the position of the arm 24 to approximately vertical.
  • the latch arm 24, as shown in Fig. 14B, has a tubular recess in its upper end that fits over the fishing neck 127 of the latch mechanism 23.
  • Two tan gential shear pins 128 fastens the arm 24 to the head 127 so that the arm can be released from the head in response to downward arring.
  • the latch mechanism 23 is a conventional device well known to those skilled in the art as a "K" latch and is available from Cameo, Inc., Houston, Texas. After the valve 21 has been set and the arm 24 released therefrom by downward jarring, the tool can be moved downward to release the arm from the latch mechanism, leaving the valve in place.
  • the flow control device 21 which may be a typical dome pressure operated gas lift valve, is shown in Figs. 13A and 13B.
  • a dome pressure acts against a bellows and tends to close a valve element against a seat. Gas under pressure in the well annulus 16 will act against the bellows and force the valve open to enable the gas to pass through the seat and into, a passage 134.
  • the passage 134 extends through a special packing sub 135 and exits to the side of the sub via one or more ports 136.
  • the sub 135 has a threaded box 137 at its upper end which screws onto -19- the end of the valve housing 138, and a threaded box 139 at its lower end which is threaded to the latch mandrel 140.
  • An annular recess 141 on the exterior of the sub 135 ⁇ receives a single set of chevron-type packing rings 142 which constitute the only packing on the flow control device 21.
  • the radial ports 136 are directed toward the centerline of the tray 20 so as to face away from the adjacent wall of the side pocket mandrel 10 when the valve is latched therein.
  • the lower section 139 of the sub 135 can be provided with an outwardly directed shoulder that extends approximately 180° therearound as shown in Fig. 15, so that the valve cannot be set with the ports 136 directed outwardly because the shoulder will not pass the inwardly directed latch shoulder 51 on the mandrel 10.
  • the lower section 112 of the tray 20 is provided with a downwardly extending collet sleeve 145 that is threaded into a bore in the section 112 a shown.
  • the sleeve 145 is longitudinally split to divide it * into a plurality of fingers 146 each having a threaded head 147 at its lower end.
  • the heads 147 will ratchet into a socket 148 in the lower end section 149 of the carrier sleeve 105 as shown in Fig. 3. Although the heads can ratchet into the socket, they must be screwed out to achieve release.
  • the carrier sleeve 105 has an elongated window cut in its outer side and through which the kick ⁇ over arm 25 and the latch arm 24 extend when the tool is activated.
  • the lower end wall 150 of the window provide a means to retain the pivot arm in position alongside the tray 20 when to tool is being removed from the well as will be described in greater detail below.
  • FIG. 12 An embodiment of a pulling arm 150 that can be used to release the flow control device 21 when it is desired to remove it from the well is shown in Fig. 12.
  • the lower -20- end of the arm is arranged to be pivoted to the outer end of the arm 25 as previously described, and the arm has a core 161 that is shear pinned to a barrel 162 at 163.
  • a plurality of latch dogs 164 having inwardly extending shoulders 165 at their upper ends are arranged to pass over the fishing neck 127 of the latch mechanism 23 and to engage above the shoulder 129 on the release sleeve 130.
  • a pin 164 (Fig.
  • the pulling arm assembly 160 is a conventional device well known to those skilled in the art.
  • the kickover tool is assembled as shown in the drawings with a running arm 24 attached to the upper end of the kickover arm 25, and a gas lift valve or- other flow control device connected to the arm 24 by a latch mechanism 23.
  • the pivot arm 25 and latch arm 24 are folded into position alongside the tray 20, and the tray is moved downward within the carrier sleeve 105 to engage the release pin 113 with the catch shoulder 120.
  • the power spring 81 is compressed by this movement, and the detent balls 83 are locked in engagement with the annular groove 84.
  • the spring-loaded dog 92 is misaligned with respect to orienting dog 26 by about 180°, and the pin 78 holds the latch rod 77 in its upper position where its head 76 prevents clockwise rotation of the dog 26. 8
  • the fishing neck 67 is then connected by a suitable socket to a set of wire line jars (not shown) which are in turn connect to the wire line that is wound on a winch.
  • the kickover tool is then lowered through the lubricator and into the tubing 11 where it is lowered until a select ⁇ ed side pocket mandrel 10 is reached.
  • the tool is lowered to a point below this side pocket mandrel, and then raised upwardly thereinto.
  • the orienting dog 26 finds the slot 33 in the orienting sleeve 13 as previously described, and the spring-loaded dog 92 enters the slot 37 shown in Fig. 6.
  • the orienting dog 26 comes up against the inclined shoulder 36 and causes the body 66 to rotate relative to the retainer cup 85 which is being held against rotation by the dog 92.
  • the release ball 87 is moved into alignment with the ball slot 90, enabling the power spring 81 to expand and force the control rod 94 downwardly relative to the tray 20.
  • the lower end of the rod 94 acts via the lug 103 to push the carrier sleeve 105 downwardly until the stop member 108 engages the shoulder surface 109, at which point the release pin 113 will have disengaged from the catch shoulder 120 on the pivot arm 25.
  • the kickover tool then is lowered to cause the collet heads 107 on the carrier sleeve 105 to catch on the recess 52 at the lower end of the mandrel 10 as shown in Fig. 3. Additional lowering of the tray 20 causes the lower window surface 150 to cam the pivot arm 25 inwardly, which brings the latch arm 24 in also. Eventually the catch sleeve 145 will ratchet into the socket 148 (see Fig. 3) to condition the assembly for removal from the well tubing. Since the orienting dog 26 is inoperative, and the pivot arm 25 is held retracted, the kickover tool can be removed from the tubing without any parts thereof dragging against the tubing wall.
  • the latch arm 24 is replaced by the pull- ing arm shown in Fig. 12.
  • the tool is run into the well as previously described, and the pivot arm 25 is activated to cause the pulling arm to be shifted to the outer posi ⁇ tion aligned with the latch mechanism 23.
  • the latch fingers 164 will automatically pass over the latch head 127 and will grasp the fishing shoulder 129.
  • a downward jarring blow will cause shearing of the pin 164 that normally holds the sleeve 130 to the latch mandrel, whereupon the sleeve can be moved downward ⁇ ly to remove its upper end from inside the latch ring 131.
  • FIG. 16A through 16C Another and perhaps preferred embodiment of the present invention is shown in Figs. 16A through 16C.
  • the housing 200 of the orienting section 201 has a fishing neck 202 threaded into its upper end.
  • the central bore 203 of the housing 200 receives a power spring 204 that pushes down on the upper end surface 205 of an upper mandrel 206 which has a key 207 pivoted thereto by a pin 208.
  • a folded leaf spring 209 biases the key 207 outward ⁇ ly.
  • the lower end of the upper mandrel 206 is provided with a U-shaped recess 210 that receives a connector lug
  • the 212 carries a second key 213 that is pivoted on a pin 214 and is biased outward by a folded leaf spring 215.
  • the upper mandrel 206 can rotate about the longitudinal axis of the housing 200 through an angle of about 30° due the width of the window opening 216 therein.
  • the housing is retained in its counterclockwise position (viewed from above) by a small projection 220 that engages in a recess 221 in a cover sleeve 222 that is fitted over the lower section of the housing 200 as shown in Fig. 22.
  • the lower end portion 223 of the lower mandrel 212 is fitted into a bore 224 of the housing 200, and has the control rod 225 attached thereto by means of a connector ' block 226 and a screw 227.
  • the orienting section 201 is "cocked" by moving the mandrels 206 and 212 upward within the housing 200 to compress the power spring 204, and then rotating the upper mandrel 206 to the left to engage the projection 220 with the notch 221.
  • the lower end of the housing 200 is threaded direct ⁇ ly .to the upper end of the tray 230 as shown in Fig. 16A.
  • the tray 230 has an elongated internal recess 232 (16B) which receives the gas lift valve 21 shown in phantom lines, and another elongated recess 233 that receives the control rod 225.
  • a slot 235 can be cut into the rear of the tray 230, and a hump 236 (Fig. 19) provided on the rod 225 which engages in a recess 237 on the sub 135 to provide for a positive positioning of the packing sub 135 when the valve is being run.
  • the lower end of the pivot arm assembly 240 is pivoted to the tray 230 by a pin 241.
  • the arm 240 is biased toward retracted position by a coil spring 242 that reacts between an outwardly facing surface 243 on the tray and a back wall surface of a recess 244 in the arm below the pivot pin 241.
  • the body 245 of the arm 240 has an internal recess 246 that slid ⁇ ably receives a plunger 247' that is biased downward by a coil spring 248.
  • a pair of oppositely extending links 249 and 249' are pivoted to the plunger 247 by a pin 250 that -25- extends through a slot in the rear wall of the tray 230 and is provided with an enlarged head 251.
  • the head 251 is received in a U-shaped slot 252 on the lower end of the control rod 225 as shown in Fig. 21.
  • a pair of wheels 253, 253' are mounted on the outer ends of the links 249 by means of pins 254.
  • the wheels are received in oppo ⁇ sitely disposed guide windows 255 in a manner such that downward movement of the plunger 247 will cause extension of the wheels, and upward movement of the plunger will cause their retraction.
  • the lower end of the body of the arm 240 is provided with a cap 260 that houses a clutch ring 261 that has upwardly facing teeth on its inner surface which engage downward facing teeth on the member 262 of a yoke 263.
  • the ring 261 is split and can expand and contract to permit the portion 262 to ratchet upward in the body 240, however the yoke must be unscrewed from the ring 261 to move it downwardly.
  • the upper end of the portion 262 is threaded into a cap 264 which is held within the lower portion of the body 240 by a shear pin 265.
  • the plunger 247 has a nose 266 that is engaged by the upper end of the cap 264 when the pin 265 is sheared and the yoke 263 ratchets upward in the clutch ring 261. Engagement of the nose with the cap 264 causes the plunger 247 to move upward, resulting in a retraction of the wheels 253 and 253' from their outer positions.
  • -26- A second embodiment of a side pocket mandrel in accordance with the present invention is shown in Figs. 23A and 23B.
  • the mandrel 300 has in its upper end section 301 an orienting sleeve 302 having lower helical guide surfaces 303 that lead upwardly to a slot 304 which opens through the top of the sleeve.
  • each rail 305 of the mandrel has a pair of oppositely disposed guide means, for examples, in the form of rails 306 that extend ⁇ ed inwardly of the side walls thereof and cooperate with the wheels 253, 253' on the above-described pivot arm 240 in a manner to force the pivot arm outwardly.
  • Each rail in the form of rails 306 that extend ⁇ ed inwardly of the side walls thereof and cooperate with the wheels 253, 253' on the above-described pivot arm 240 in a manner to force the pivot arm outwardly.
  • each rail section 308 is extended upward in a direction generally parallel to the axis of the main bore 309 of the mandrel.
  • the upper end of each rail terminates at a prescribed distance below the latch shoulder 51 and the cylindrical packing bore 29.
  • the guides could be formed by grooves in the walls of the mandrel or by outwardly facing shelves or ledges on the mandrel walls.
  • the ramp sections of the rails could be formed as inclined surfaces or sleeve which is secured in the lower swage nipple.
  • a gas lift valve 21 or other flow control device is attached to the running arm 24' by a latch assembly 23, and the valve, running arm and pivot arm 25' are folded against the tray 230.
  • the upper and lower mandrels 206 and 212 of the orienting section 201 are shifted upwardly against the bias of the power spring 204, and the upper mandrel 206 and key 207 are rotated to the left to position the key 207 out of alignment with the lower key 213 and to engage the projection 220 with the -27- notch 221.
  • This movement shifts the control rod 225 upward to maintain the guide wheels 253 and 253' in their retracted positions.
  • the kickover tool is connected to the wire line and associated equipment such as sinker bar and a jar, and lowered into the tubing 11.
  • the keys 213 and 207 ' pass restrictions in the tubing bore, they merely pivot inward ⁇ ly to bypass such restrictions.
  • the mandrel 10 is reached in which it is desired to set the valve 21, the tool is lowered to a position below the mandrel and then lifted upward.
  • the entire tool assembly 201 is rotated to a position such that the nose of the valve 21 initially is 30° to the right of the packing bore 29.
  • the cap 264 engages the nose 266 of the plunger 247 and drive it upward.
  • the upward movement of the plunger 247 effects a retraction of the wheels 253 so that they no longer engage the outer surfaces of the rail sections 303.
  • the tool is first lowered within the mandrel 300.
  • the wheels 253 have been retracted as described above, and the coil spring 242 is forcing the pivot arm 25'.
  • the pivot arm 25' and the running arm 24 can retract to their running positions alongside the tray 230, and the entire assembly can be withdrawn from the tubing.
  • a pulling arm assembly as shown in Fig. 12 is substituted for the latch arm 24, and downward jarring is used to release the latch mechanism 23.
  • the mandrel in being provided with a packing bore that is slightly inclined toward the center line of the main bore, provides a construction where placement and removal of a flow control device is greatly facilitated. The instances of latch and valve damage during removal are greatly reduced.
  • the single packing employed on the flow control device provides an assembly that is considerably -29- easier to remove as compared to prior devices, and the feature of having a packing diameter that is greater than the diameter of the valve body also contributes to the ease with which a valve can be removed.
  • the orienting section of the kickover tool has a unique arrangement of keys which orient and release the pivot arm, and the valve is positively guided into engagement with the packing bore of the mandrel during placement operations.
  • the port sub of the valve also is uniquely arranged to cause the direction of gas flow to be toward the inside of the mandrel and away from the adjacent wall surfaces.
  • the valve is positioned in the well annulus so that it is substantially isolated from the effects of variations in temperature of well production fluids due to lift gas mixing and other variables, and it is possible, and perhaps even desirable, to use a conventional gas lift valve in combination with the unique packing and port sub of the present invention.
  • a side pocket mandrel assembly indicated generally at 410 includes an upper tubular member 411 having internal threads 399 for ' connecting the same to a string of production tubing (not shown) .
  • the tubular member 411 is secured by a transverse weld 455 to a seating section 412 of relatively short length, and the section 412 is secured by a transverse weld 456 to a main body section 413.
  • the main body section 413 preferably is circular in cross-section, and one side 414 of the hollow interior thereof is axially aligned with the bore of the tubular member 411.
  • the other side 415 of the hollow interior provides an elongated space for operation of the kickover arm of a gas lift valve setting or retrieving tool, such arm being typically a segmented subassembly that can be pivoted outward in order to align a valve attached to the end thereof for insertion into a valve seat or pocket in the mandrel.
  • the lower end of the main body section 413 is -30- secured by a transverse weld 457 to a swage nipple 416 that has internal threads 417 for connection to the tubing.
  • the tubular member 411 can have an orienting sleeve 420 fixed within the bore thereof.
  • the sleeve 420 has a pair of helical lower surfaces 421 that lead upward to an elongated vertical slot 422.
  • the slot 422 is arranged to receive a key on a setting tool as it is moved upward therethrough, in order to rotationally orient the tool in a manner such that the kickover arm and valve are generally aligned within the region 415 of the body section 413.
  • Such orientation is achieved by the fact that the key will first encounter one of the inclined surfaces 421 and be guided thereby into the slot 422.
  • a second key that initially .is vertically misaligned with the first-mentioned key will then encounter one of the surfaces 421 during continued upward movement, and the camming action as the keys are forced into vertical alignment achieves proper orientating and causes- the kickover tool to trigger the release of guide rollers or wings on the arm assembly.
  • the wings then cause the inwardly biased arm assembly to be pivoted outward during continued upward movement.
  • the seating section 412 of the present invention is shown in detail in Figures 25 and 26.
  • the section 412 is generally tubular, and has a main bore 425 machined to one side thereof.
  • the upper end of the bore 425 opens through an annular lip 426 which is chamfered to facilitate welding to the lower end of the tubular member 411.
  • Another bore 427 is formed on the opposite side of the section 412, and has its central axis 428 slightly inclined downward and inward with respect to the axis 429 of the main bore 425.
  • the angle of inclination may be, for example, from 1-1/2° to 3°.
  • the upper end portion 430 of the bore 427 has a reduced diameter (for example 1.125 inches) , and is machined as a polish bore that receives an -31 - annular packing assembly of a gas lift valve or other flow control device shown in phantom lines in Figure 24.
  • the bore 430 opens to the outside of the mandrel at its upper end as shown, and is joined by an annular inclined surface 431 to a larger diameter bore 432 which receives the latch element (for example collet) of a typical latch assembly which releasably connect the gas lift valve, or other flow control device, in place.
  • the latch element has shoulder surfaces that engage an inclined shoulder 433 at the lower end of the enlarged bore 432, and the shoulder 433 forms the upper side of an inwardly directed flange 434 that has another inclined annular shoulder 435 at its lower side.
  • the shoulder 435 is at the upper end of another enlarged diameter bore 436 that opens through the lower end surfaces 440 of the section 412.
  • the lower end of the section 412 is beveled at 437, again to facilitate welding to the upper end of the main body section 413.
  • a generally frusto-conical surface 440 is machined in the lower portion of the section 412 as shown, and a vertical slot 441 is milled out in the wall that separates the bores 430 and 425 in order to provide for the inward flow of lift gas.
  • the slot 441 extends upward to a point 442 adjacent the "no go 1 ' shoulder 431, and" preferably has a width such that the latch shoulder 433 extends circumferentially through an angle of about 290 e> (145° to either side of a radial line that intersects the respective centerlines of the bores 428 and 429) to provide ample stop surface area for the latch element.
  • the slot 441 also functions as a guide for proper rotational orientation of the body of the gas lift valve to radially align a port in the neck of the valve such that the lift gas is injected into the bore 425 where it is admixed and entrained in the upward flow of production fluids.
  • the central bore 425 may have a transverse dimension of, for example, 2.750 inches up to -32- an inclined surface 443 where the diameter is reduced to 2.441 inches, which is the same dimension as the inner diameter of the orienting sleeve 420.
  • these dimensions are applicable to a typical size side pocket 5 mandrel, for example a mandrel sized to be connected in a 2-7/8" o.d. tubing string.
  • the swage nipple 415 shown in Figure IB has fixed therein a ramp member 450 that is generally semi-circular in section and has inclined surfaces 451 and 452 on
  • the upper and lower ends of the member 450 can be oppositely inclined, as shown, so that no transverse shoulders are formed which could cause other tools to hang up on the member. If desired, a pair of oppositely disposed, elongated rails 451 are mounted
  • each rail 451 may be inclined at 453 to present a
  • tubular member 411 is joined to the upper end of the receptacle section 412 by
  • transverse weld 455 the transverse weld 455, and the lower end of the receptacle section 412 is joined to the upper end of the body section 413 by the transverse weld 456.
  • the lower end of the body 413 is joined to the swage nipple by a transverse weld 457.
  • a guard lug 460 may be fixed to the outside of the tubular member 411 at a distance from the upper end -33- of the section 412 such that it is closely adjacent the nose of the gas lift valve when the valve is latched in place.
  • the lug prevents the valve from being damaged in the event the tubing is moved upward in the casing while the valve is in place.
  • the guard lug 460' may have a polish bore 462 formed therein on a diameter that is slightly less than the diameter of the bore 430, for example 1.000 inch.
  • a gas flow port 463 communicates the polish bore 462 with the interior bore of the tubular member 412. This feature enables a more conventional gas lift valve to be used having spaced apart packing rings that engage the respective bores 430 and 461, and a gas outlet port through the end of the nose thereof which is packed off in the bore 462.
  • the member 412 which houses an orienting sleeve 420 could be attached to a swage nipple and body section as previously described, except inverted, or turned upside-down.
  • the seating section 413 would be inverted also and would be located near the lower end of the mandrel, whereby the polish bore 430 would open downward.
  • the tubular member to which the section 413 is welded, in this configuration would not have an orienting sleeve therein.

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  • Geology (AREA)
  • Life Sciences & Earth Sciences (AREA)
  • Engineering & Computer Science (AREA)
  • Mining & Mineral Resources (AREA)
  • Geochemistry & Mineralogy (AREA)
  • Fluid Mechanics (AREA)
  • Environmental & Geological Engineering (AREA)
  • General Life Sciences & Earth Sciences (AREA)
  • Physics & Mathematics (AREA)
  • Mechanically-Actuated Valves (AREA)
  • Lift Valve (AREA)
  • Automatic Tool Replacement In Machine Tools (AREA)
  • Escalators And Moving Walkways (AREA)
  • Accommodation For Nursing Or Treatment Tables (AREA)
  • Moulds For Moulding Plastics Or The Like (AREA)
  • Molds, Cores, And Manufacturing Methods Thereof (AREA)
  • Storage Of Web-Like Or Filamentary Materials (AREA)

Abstract

Selon les modes de réalisation illustrant la présente invention, un mandrin (10, 410) possédant sur le côté une poche latéralement décentrée par rapport à l'alésage ouvert (425) comporte une ouverture (29, 430) à l'extrémité supérieure adaptée pour recevoir un clapet à gaz (21). L'axe (428) de l'ouverture est incliné vers le bas et l'intérieur en direction de l'axe (429) de l'alésage ouvert. L'ouverture peut être formée dans une partie à siège de faible longueur (412) qui est soudée à une extrémité d'un tronçon (413) du corps central. Un outil de renversement (420) pour remplacer et retirer les soupapes comporte une partie à orientation (60) possédant des crabots (26, 92) à espacement angulaire qui interagissent avec un manchon du mandrin pour orienter l'outil et déclencher le mouvement longitudinal d'une tige de commande (94). A la suite des mouvements de la tige, des guides situés sur un bras de pivotement (24) agissant sur des rampes (450) ou des éléments semblables dans le mandrin provoquent le passage de la soupape à travers l'ouverture pour qu'elle atteigne une position avec dépassement vertical dans l'anneau, un sub de garniture qui lui est attaché étant engagé dans l'ouverture.
PCT/US1985/002411 1984-12-07 1985-12-04 Appareil pour mettre en place et retirer des dispositifs de commande de l'ecoulement dans les puits WO1986003544A2 (fr)

Priority Applications (1)

Application Number Priority Date Filing Date Title
DE8686900445T DE3579457D1 (de) 1984-12-07 1985-12-04 Mantelrohr mit seitentasche.

Applications Claiming Priority (4)

Application Number Priority Date Filing Date Title
US06/679,263 US4765403A (en) 1984-12-07 1984-12-07 Apparatus for placing and removing well flow control devices
US06/789,313 US4715441A (en) 1985-10-18 1985-10-18 Side pocket mandrel
US789,313 1985-10-18
US679,263 1991-04-02

Publications (2)

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WO1986003544A2 true WO1986003544A2 (fr) 1986-06-19
WO1986003544A3 WO1986003544A3 (fr) 1986-07-31

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Country Link
EP (3) EP0204823B1 (fr)
AU (3) AU585298B2 (fr)
DE (1) DE3579457D1 (fr)
WO (1) WO1986003544A2 (fr)

Cited By (5)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US4744415A (en) * 1987-04-24 1988-05-17 Crawford Douglass W Kickover tool for placing and removing well flow control devices
WO1989007189A1 (fr) * 1988-02-03 1989-08-10 Crawford William B Mandrel a fente en t et outil de renversement
US4976314A (en) * 1988-02-03 1990-12-11 Crawford William B T-slot mandrel and kickover tool
US5058670A (en) * 1989-05-15 1991-10-22 Crawford Douglas W Oriented valve and latch for side pocket mandrel
NO342890B1 (en) * 2017-03-29 2018-08-27 Petroleum Technology Co As Well component with deflector surface

Families Citing this family (1)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US4624309A (en) * 1984-09-24 1986-11-25 Otis Engineering Corporation Apparatus for monitoring a parameter in a well

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US2664162A (en) * 1948-06-24 1953-12-29 Sid W Richardson Inc Means for installing and removing flow valves
US2679904A (en) * 1949-11-23 1954-06-01 Sid W Richardson Inc Means of installing and removing flow valves or the like
US2679903A (en) * 1949-11-23 1954-06-01 Sid W Richardson Inc Means for installing and removing flow valves or the like
US2824525A (en) * 1954-07-26 1958-02-25 Sid W Richardson Inc Offset mandrel for small diameter tubing
US3075586A (en) * 1958-07-02 1963-01-29 Otis Eng Co Nipple with lateral port control
US3268006A (en) * 1962-09-10 1966-08-23 Shell Oil Co Method and apparatus for installing and retrieving well tools in well strings
US3741299A (en) * 1971-12-15 1973-06-26 Camco Inc Sidepocket mandrel
US3771597A (en) * 1972-09-11 1973-11-13 Camco Inc Fluid system for moving subsurface well equipment in well tubing
US3802503A (en) * 1972-03-01 1974-04-09 Ginn F Mc Well tubing mandrel with combination guard and guide
US3939705A (en) * 1973-03-02 1976-02-24 Schlumberger Technology Corporation Removable downhole measuring instruments with electrical connection to surface
US4106563A (en) * 1977-11-03 1978-08-15 Camco, Incorporated Sidepocket mandrel
GB2115456A (en) * 1982-02-19 1983-09-07 Otis Eng Co Side pocket mandrel

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US2988146A (en) * 1958-06-02 1961-06-13 Otis Eng Co Offset mandrel and tools
US4524833A (en) * 1983-09-23 1985-06-25 Otis Engineering Corporation Apparatus and methods for orienting devices in side pocket mandrels

Patent Citations (12)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US2664162A (en) * 1948-06-24 1953-12-29 Sid W Richardson Inc Means for installing and removing flow valves
US2679904A (en) * 1949-11-23 1954-06-01 Sid W Richardson Inc Means of installing and removing flow valves or the like
US2679903A (en) * 1949-11-23 1954-06-01 Sid W Richardson Inc Means for installing and removing flow valves or the like
US2824525A (en) * 1954-07-26 1958-02-25 Sid W Richardson Inc Offset mandrel for small diameter tubing
US3075586A (en) * 1958-07-02 1963-01-29 Otis Eng Co Nipple with lateral port control
US3268006A (en) * 1962-09-10 1966-08-23 Shell Oil Co Method and apparatus for installing and retrieving well tools in well strings
US3741299A (en) * 1971-12-15 1973-06-26 Camco Inc Sidepocket mandrel
US3802503A (en) * 1972-03-01 1974-04-09 Ginn F Mc Well tubing mandrel with combination guard and guide
US3771597A (en) * 1972-09-11 1973-11-13 Camco Inc Fluid system for moving subsurface well equipment in well tubing
US3939705A (en) * 1973-03-02 1976-02-24 Schlumberger Technology Corporation Removable downhole measuring instruments with electrical connection to surface
US4106563A (en) * 1977-11-03 1978-08-15 Camco, Incorporated Sidepocket mandrel
GB2115456A (en) * 1982-02-19 1983-09-07 Otis Eng Co Side pocket mandrel

Cited By (7)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US4744415A (en) * 1987-04-24 1988-05-17 Crawford Douglass W Kickover tool for placing and removing well flow control devices
WO1989007189A1 (fr) * 1988-02-03 1989-08-10 Crawford William B Mandrel a fente en t et outil de renversement
US4976314A (en) * 1988-02-03 1990-12-11 Crawford William B T-slot mandrel and kickover tool
US5058670A (en) * 1989-05-15 1991-10-22 Crawford Douglas W Oriented valve and latch for side pocket mandrel
NO342890B1 (en) * 2017-03-29 2018-08-27 Petroleum Technology Co As Well component with deflector surface
NO20170516A1 (en) * 2017-03-29 2018-08-27 Petroleum Technology Co As Well component with deflector surface
US11111746B2 (en) 2017-03-29 2021-09-07 Petroleum Technology Company As Wellbore arrangement

Also Published As

Publication number Publication date
AU3955389A (en) 1989-11-30
EP0345830A3 (fr) 1990-01-17
AU585298B2 (en) 1989-06-15
DE3579457D1 (de) 1990-10-04
EP0204823B1 (fr) 1990-08-29
EP0351884A1 (fr) 1990-01-24
EP0204823A1 (fr) 1986-12-17
AU3955189A (en) 1989-11-30
AU5206086A (en) 1986-07-01
EP0345830A2 (fr) 1989-12-13
WO1986003544A3 (fr) 1986-07-31

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