EP2484862B1 - Manche d'indexation pour fracturation multi-niveaux en une seule manoeuvre - Google Patents

Manche d'indexation pour fracturation multi-niveaux en une seule manoeuvre Download PDF

Info

Publication number
EP2484862B1
EP2484862B1 EP12151459.0A EP12151459A EP2484862B1 EP 2484862 B1 EP2484862 B1 EP 2484862B1 EP 12151459 A EP12151459 A EP 12151459A EP 2484862 B1 EP2484862 B1 EP 2484862B1
Authority
EP
European Patent Office
Prior art keywords
insert
catch
bore
condition
plug
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.)
Not-in-force
Application number
EP12151459.0A
Other languages
German (de)
English (en)
Other versions
EP2484862A2 (fr
EP2484862A3 (fr
Inventor
Clark E. Robison
Robert Coon
Robert Malloy
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.)
Weatherford Technology Holdings LLC
Original Assignee
Weatherford Technology Holdings LLC
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 US13/022,504 external-priority patent/US8403068B2/en
Application filed by Weatherford Technology Holdings LLC filed Critical Weatherford Technology Holdings LLC
Publication of EP2484862A2 publication Critical patent/EP2484862A2/fr
Publication of EP2484862A3 publication Critical patent/EP2484862A3/fr
Application granted granted Critical
Publication of EP2484862B1 publication Critical patent/EP2484862B1/fr
Not-in-force legal-status Critical Current
Anticipated expiration legal-status Critical

Links

Images

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
    • E21B34/00—Valve arrangements for boreholes or wells
    • E21B34/06—Valve arrangements for boreholes or wells in wells
    • E21B34/14—Valve arrangements for boreholes or wells in wells operated by movement of tools, e.g. sleeve valves operated by pistons or wire line tools
    • E21B34/142—Valve arrangements for boreholes or wells in wells operated by movement of tools, e.g. sleeve valves operated by pistons or wire line tools unsupported or free-falling elements, e.g. balls, plugs, darts or pistons
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B2200/00—Special features related to earth drilling for obtaining oil, gas or water
    • E21B2200/06—Sleeve valves

Definitions

  • frac operations During frac operations, operators want to minimize the number of trips they need to run in a well while still being able to optimize the placement of stimulation treatments and the use of rig/frac equipment. Therefore, operators prefer to use a single-trip, multistage fracing system to selectively stimulate multiple stages, intervals, or zones of a well.
  • this type of fracing systems has a series of open hole packers along a tubing string to isolate zones in the well. Interspersed between these packers, the system has frac sleeves along the tubing string. These sleeves are initially closed, but they can be opened to stimulate the various intervals in the well.
  • the system is run in the well, and a setting ball is deployed to shift a wellbore isolation valve to positively seal off the tubing string. Operators then sequentially set the packers. Once all the packers are set, the wellbore isolation valve acts as a positive barrier to formation pressure.
  • the dropped balls engage respective seat sizes in the frac sleeves and create barriers to the zones below.
  • Applied differential tubing pressure then shifts the sleeve open so that the treatment fluid can stimulate the adjacent zone.
  • Some ball-actuated frac sleeves can be mechanically shifted back into the closed position. This gives the ability to isolate problematic sections where water influx or other unwanted egress can take place.
  • the smallest ball and ball seat are used for the lowermost sleeve, and successively higher sleeves have larger seats for larger balls.
  • practical limitations restrict the number of balls that can be run in a single well. Because the balls must be sized to pass through the upper seats and only locate in the desired location, the balls must have enough difference in their sizes to pass through the upper seats.
  • US patent application 2008/0093080 discloses a downhole circulation valve which can perform a series of operations which are actuated by balls of the same size.
  • US patent application 2010/0282338 discloses a downhole movable seat with a counter, the seat being responsive to the number of balls which have passed therethrough.
  • WO 2010/127457 discloses a tubing string assembly for treating selected regions of a wellbore, the assembly having a sliding sleeve which is actuated to an operative position by an actuator ball, the sleeve in its operative position being responsive to a second ball.
  • some operators have used selective darts that use onboard intelligence to determine when the desired seat has been reached as the dart deploys downhole.
  • the subject matter of the present disclosure is directed to overcoming, or at least reducing the effects of, one or more of the problems set forth above.
  • Downhole flow tools or sliding sleeves deploy on a tubing string down a wellbore for a frac operation or the like.
  • the tools have an insert and a sleeve that can move in the tool's bore.
  • Various plugs such as balls, frac darts, or the like, deploy down the tubing string to selectively isolate various zones of a formation for treatment.
  • the insert moves by fluid pressure from a first port in the tool's housing.
  • the insert defines a chamber with the tool's housing, and the first port communicates with this chamber.
  • the first port in the tool's housing is opened by an actuator, fluid pressure from the annulus enters this open first port and fills the chamber.
  • the insert moves from a first position to a second position away from the sleeve by the piston action of the fluid pressure.
  • the insert is biased by a spring from a first position to a second position.
  • One or more pins or arms retain the biased insert in the first position.
  • the spring moves the insert from the first position to the second position away from the sleeve.
  • the sleeve has a catch that can be used to move the sleeve. Initially, this catch is inactive when the insert is positioned toward the sleeve in the first position. Once the insert moves away due to filling of the chamber or bias of the spring by the actuator, however, the catch becomes active and can engage a plug deployed down the tubing string to the catch.
  • the catch is a profile defined around the inner passage of the sleeve.
  • the insert initially conceals this profile until moved away by the actuator. Once the profile is exposed, biased dogs or keys on a dropped plug can engage the profile. Then, as the plug seals in the inner passage of the sleeve, fluid pressure pumped down the tubing string to the seated plug forces the sleeve to an open condition. At this point, outlet ports in the tool's housing permit fluid communication between the tool's bore and the surrounding annulus. In this way, frac fluid pumped down to the tool can stimulate an isolated interval of the wellbore formation.
  • a reverse arrangement for the catch can also be used.
  • the sleeve in the tool has dogs or keys that are held in a retracted condition when the insert is positioned toward the sleeve. Once the insert moves away from the sleeve by the actuator, the dogs or keys extend outward into the interior passage of the sleeve. When a plug is then deployed down the tubing string, it will engage these extended keys or dogs, allowing the sleeve to be forced open by applied fluid pressure.
  • the indexing sleeve or tool has an actuator for activating when the insert moves away from the sleeve so the next dropped plug can be caught.
  • the actuator has a sensor, such as a hall effect sensor, and one or more flexure members or springs. When a plug passes through the tool, the flexure members trigger the sensor to count the passage of the plug.
  • Control circuitry of the actuator uses a counter to count how many plugs have passed through the tool. Once the count reaches a preset number, the control circuitry activates a valve, which can be a solenoid valve or other mechanism.
  • the valve can have a plunger or other form of closure for controlling fluid communication to move the insert. Alternatively, the valve can move a pin or arm to release the insert, which then moves by the bias of a spring.
  • a downhole flow apparatus comprising:
  • a downhole flow tool comprising:
  • a wellbore fluid treatment system comprising:
  • the actuator can comprise at least one flexure member disposed in the bore, the at least one flexure member movable from an unflexed condition to a flexed condition by engagement with the plugs, the actuator responsive to the at least one flexure member in the flexed condition and moving the insert from the first position to the second position in response thereto.
  • a tubing string 12 shown in Fig. 1 deploys in a wellbore 10.
  • the string 12 has flow tools or indexing sleeves 100A-C disposed along its length.
  • Various packers 40 isolate portions of the wellbore 10 into isolated zones.
  • the wellbore 10 can be an opened or cased hole, and the packers 40 can be any suitable type of packer intended to isolate portions of the wellbore into isolated zones.
  • the indexing sleeves 100A-C deploy on the tubing string 12 between the packers 40 and can be used to divert treatment fluid selectively to the isolated zones of the surrounding formation.
  • the tubing string 12 can be part of a frac assembly, for example, having a top liner packer (not shown), a wellbore isolation valve (not shown), and other packers and sleeves (not shown) in addition to those shown. If the wellbore 10 has casing, then the wellbore 10 can have casing perforations 14 at various points.
  • operators deploy a setting ball to close the wellbore isolation valve (not shown). Then, operators rig up fracing surface equipment and pump fluid down the wellbore to open a pressure actuated sleeve (not shown) toward the end of the tubing string 12. This treats a first zone of the formation. Then, in a later stage of the operation, operators selectively actuate the indexing sleeves 100A-C between the packers 40 to treat the isolated zones depicted in Fig. 1 .
  • the indexing sleeves 100A-C have activatable catches (not shown) according to the present disclosure. Based on a specific number of plugs (i.e., darts, balls or the like) dropped down the tubing string 12, internal components of a given indexing sleeve 100A-C activate and engage the dropped plug. In this way, one sized plug can be dropped down the tubing string 12 to open the indexing sleeve 100A-C selectively.
  • plugs i.e., darts, balls or the like
  • indexing sleeves 100 With a general understanding of how the indexing sleeves 100 are used, attention now turns to details of indexing sleeves 100 according to the present disclosure. Various indexing sleeves 100 are disclosed in co-pending application Ser. No. 12/753,331 , which has been incorporated herein by reference.
  • the indexing sleeve 100 has a housing 110 defining a bore 102 therethrough and having ends 104/106 for coupling to a tubing string (not shown). Inside, the housing 110 has two inserts ( i.e., insert 120 and sleeve 140) disposed in its bore 102.
  • the insert 120 can move from a closed position ( Fig. 2 ) to an open position (not shown) when an appropriate plug ( e.g., dart 150 of Fig. 4 or other form of plug) is passed through the indexing sleeve 100 as discussed in more detail below.
  • the sleeve 140 can move from a closed position ( Fig. 2 ) to an opened position (not shown) when another appropriate plug (e.g. dart 150 or other form of plug) is passed later through the indexing sleeve 100 as also discussed in more detail below.
  • the insert 120 in the closed condition covers a portion of the sleeve 140.
  • the sleeve 140 in the closed condition covers external ports 112 in the housing 110, and peripheral seals 142 on the sleeve 140 prevent fluid communication between the bore 102 and these ports 112.
  • the insert 120 is moved away from the sleeve 140 so that a profile 146 on the sleeve 140 is exposed in the housing's bore 102.
  • the sleeve 140 in the open position is moved away from the ports 112 so that fluid in the bore 102 can pass out through the ports 112 to the surrounding annulus and treat the adjacent formation.
  • an actuator or controller 130 having control circuitry 131 in the indexing sleeve 100 is programmed to allow a set number of plugs to pass through the indexing sleeve 100 before activation. Then, the indexing sleeve 100 runs downhole in the closed condition as shown in Fig. 2 . To then begin a frac operation, operators drop a plug down the tubing string from the surface. This plug can be intended to close a wellbore isolation valve or open another indexing sleeve.
  • one type of plug for use with the indexing sleeve is a frac dart 160 having an external seal 162 disposed thereabout for engaging in the sleeve (140).
  • the dart 160 also has retractable X-type keys 166 (or other type of dog or key) that can retract and extend from the dart 160.
  • the dart 160 has a sensing element 164. In one arrangement, this sensing element 164 is a magnetic strip or element disposed internally or externally on the dart 160.
  • the dart 160 eventually reaches the indexing sleeve 100 of Fig. 2 . Because the insert 120 covers the profile 146 in the sleeve 140, the dropped dart 160 cannot land in the sleeve's profile 146 and instead continues through most of the indexing sleeve 100. Eventually, the sensing element 164 of the dart 160 meets up with a sensor 134 disposed in the housing's bore 102.
  • this sensor 134 communicates an electronic signal to the control circuitry 131 in response to the passing sensing element 164.
  • the control circuitry 131 can be on a circuit board housed in the indexing sleeve 100 or elsewhere.
  • the signal indicates when the dart's sensing element 164 has met the sensor 134.
  • the sensor 134 can be a Hall Effect sensor or any other sensor triggered by magnetic interaction.
  • the sensor 134 can be some other type of electronic device.
  • the sensor 134 could be some form of mechanical or electromechanical switch, although an electronic sensor is preferred.
  • the control circuitry 131 uses the sensor's signal to count, detects, or reads the passage of the sensing element 164 on the dart 160, which continues down the tubing string (not shown). The process of dropping a dart 160 and counting its passage with the sensor 134 is then repeated for as many darts 160 the sleeve 100 is set to pass. Once the number of passing darts 160 is one less than the number set to open this indexing sleeve 100, the control circuitry 131 activates a valve, motor, or the like 136 on the tool 100 when this second to last dart 160 has passed and generated a sensor signal. Once activated, the valve 136 moves a plunger 138 that opens a port 118 in the housing 110. This communicates a first sealed chamber 116a between the insert 120 and the housing 110 with the surrounding annulus, which is at higher pressure.
  • Fig. 3 shows the actuator or controller 130 for the disclosed indexing sleeve 100 in additional detail.
  • the sensor 134 such as a Hall Effect sensor, responds to the sensing element or magnetic strip 162 of the dart 160 when it comes into proximity to the senor 134.
  • a counter 133 that is part of the control circuitry 131 counts the passage of the dart's element 162. When a preset count has been reached, the counter 133 activates a switch 135, and a power source 132 activates a solenoid valve 136, which moves a plunger 138 to open the port 118.
  • a solenoid valve 136 can be used, any other mechanism or device capable of maintaining a port closed with a closure until activated can be used.
  • a device can be activated electronically or mechanically.
  • a spring-biased plunger could be used to close off the port.
  • a filament or other breakable component can hold this biased plunger in a closed state to close off the port.
  • an electric current, heat, force or the like can break the filament or other component, allowing the plunger to open communication through the port.
  • the insert 120 shears free of shear pins 121 to the housing 120. Now freed, the insert 120 moves (downward) in the housing's bore 102 by the piston effect of the filling chamber 116a. Once the insert 120 has completed its travel, its distal end exposes the profile 146 inside the sleeve 140.
  • next dart 160 reaches the exposed profile 146 on the sleeve 140 in Fig. 2 .
  • the biased keys 166 on the dart 160 extend outward and engage or catch the profile 146.
  • the key 166 has a notch locking in the profile 146 in only a first direction tending to open the sleeve 120. The rest of the key 166, however, allows the dart 160 move in a second direction opposite to the first direction so it can be produced to the surface as discussed later.
  • the dart's seal 162 seals inside an interior passage or seat in the sleeve 140. Because the dart 160 is passing through the sleeve 140, interaction of the seal 164 with the surrounding sleeve 140 can tend to slow the dart's passage. This helps the keys 166 to catch in the exposed profile 146.
  • the indexing sleeve 100 shown in Figs. 5A-5B has many of the same components as other sleeves disclosed herein so that like reference numbers are used for similar components.
  • the indexing sleeve 100 has a housing 110 defining a bore 102 therethrough and having ends 104/106 for coupling to a tubing string (not shown). Inside, the housing 110 has two inserts (i.e., insert 120 and sleeve 140) disposed in its bore 102.
  • the insert 120 can move from a closed position ( Fig. 5A ) to an open position (not shown) when an appropriate plug (e.g ., ball, dart, or other form of plug) is passed through the indexing sleeve 100 as discussed in more detail below.
  • an appropriate plug e.g ., ball, dart, or other form of plug
  • the sleeve 140 can move from a closed position ( Fig. 5A ) to an opened position (not shown) when another appropriate plug (e.g. ball, dart, or other form of plug) is passed later through the indexing sleeve 100 as also discussed in more detail below.
  • another appropriate plug e.g. ball, dart, or other form of plug
  • the indexing sleeve 100 is run in the hole in a closed condition.
  • the insert 120 in the closed condition covers a portion of the sleeve 140.
  • the sleeve 140 in the closed condition covers external ports 112 in the housing 110, and peripheral seals 142 on the sleeve 140 prevent fluid communication between the bore 102 and these ports 112.
  • the insert 120 has the open condition, the insert 120 is moved away from the sleeve 140 so that a profile 146 on the sleeve 140 is exposed in the housing's bore 102.
  • the sleeve 140 in the open position is moved away from the ports 112 so that fluid in the bore 102 can pass out through the ports 112 to the surrounding annulus and treat the adjacent formation.
  • the actuator or controller 130 having the control circuitry 131 in the indexing sleeve 100 is programmed to allow a set number of plugs to pass through the indexing sleeve 100 before activation. Then, the indexing sleeve 100 runs downhole in the closed condition as shown in Figs. 5A-5B . To then begin a frac operation, operators drop plugs down the tubing string from the surface.
  • a plug 170 is dropped down the tubing string, and the plug 170 eventually reaches the indexing sleeve 100.
  • This plug 170 is shown as a ball, but can be another type of plug.
  • the insert 120 covers the profile 146 in the sleeve 140, the dropped plug 170 cannot land in the sleeve's profile 146 and instead continues through most of the indexing sleeve 100.
  • the plug 170 meets up with one or more flexure members 135 disposed in the housing's bore 102 as shown in Fig. 5B .
  • the one or more flexure members 135 can be bow springs or leaf springs disposed around the perimeter of the inside bore 112. In one arrangement, as many as six springs 135 may be used. Each spring 135 is designed to support a portion of the kinetic energy of the plug 170 as it is pumped through the indexing sleeve 100. The force required to pump the plug 170 past the springs 135 can be about 1500-psi, which is observable from the surface during the pumping operations.
  • springs 135 can be used and can be uniformly arranged around the bore 112.
  • the bias of the springs 135 can be configured for a particular implementation, expected pressures, expected number of plugs to pass, and other pertinent variables.
  • the springs 135 are robust enough to provide a surface indication, but they are preferably not prone to stick due to the presence of fracproppant materials.
  • the sensor 134 is connected to a power source (e.g ., battery) 132.
  • a power source e.g ., battery
  • the plug 150 engages the springs 135, forced pumping of the plug 170 down the sleeve 100 causes the plug 150 to flex or extend the springs 135.
  • the springs 135 elongate. At full extension, ends of the springs 135 engage the sensor 134 in the bore 112, and the presence of the tip of the spring 135 near the sensor 134 indicates passage of a plug.
  • the sensor 134 communicates an electronic signal to the control circuitry 131 of the actuator or controller 130 in response to the spring contact.
  • the indexing sleeve of Figs. 5A-5B can use an actuator 130 similar to that disclosed previously in Fig. 3 .
  • the control circuitry 131 can be on a circuit board housed in the indexing sleeve 100 or elsewhere.
  • the signal indicates when the plug 170 has moved into or past the springs 135.
  • the sensor 134 can be a Hall Effect sensor or any other sensor triggered by interaction with the spring 135.
  • the sensor 134 can be some other type of electronic device.
  • the sensor 134 could be some form of mechanical or electromechanical switch, although an electronic sensor is preferred.
  • the control circuitry 131 uses the sensor's signal to count, detects, or reads the passage of the plug 170, which continues down the tubing string (not shown). The process of dropping a plug 170 and counting its passage with the sensor 134 is then repeated for as many plugs 170 the sleeve 100 is set to pass. Once the number of passing plugs 170 is one less than the number set to open this indexing sleeve 100, the control circuitry 131 activates a valve 136 on the sleeve 100 when this second to last plug 170 has passed and generated a sensor signal.
  • valve 136 moves a plunger 168 that opens a port 118, and the filling chamber 116a shears the insert 120 free of shear pins 121 to the housing 120. Now freed, the insert 120 moves (downward) in the housing's bore 102 by the piston effect. Once the insert 120 has completed its travel, its distal end exposes the profile 146 inside the sleeve 140. To now open this particular indexing sleeve 100, operators drop the next plug, which can be a frac dart 180 as in Fig. 6 .
  • the plug that can be used to index and open the sleeve can be a frac dart 180.
  • This frac dart 180 is similar to that described previously.
  • the dart 180 has an external seal 182 disposed thereabout for engaging in the sleeve (140).
  • the dart 180 also has retractable X-type keys 186 (or other type of dog or key) that can retract and extend from the dart 180.
  • this frac dart 180 can lack a sensing element because interaction of the frac dart 180 with the springs (135) on the indexing sleeve (100) indicates passage of the dart 180.
  • Figs. 7A-7C illustrate another indexing sleeve 100 according to the present disclosure in a closed condition.
  • the indexing sleeve 100 is similar to that described previously so that the same reference numbers are used for like components.
  • the indexing sleeve 100 runs in the hole in a closed condition, and the insert 120 covers a portion of the sleeve 140.
  • the sleeve 140 covers external ports 112 in the housing 110.
  • the sensor 134 detects the interaction of the end of the flexure members or springs 135, and the control circuitry 131 of the actuator 130 counts the passage of the plug 170. The process of dropping a plug 170 and counting its passage with the sensor 134 is then repeated for as many plugs 170 the sleeve 100 is set to pass.
  • the control circuitry 131 activates a valve, motor, or the like 136 on the sleeve 100 when this second to last plug 170 has passed and generated a sensor signal. Once activated, the valve 136 moves an arm or pin 139 restraining the insert 120. Once the insert 120 is unrestrained, a spring 125 biases the insert 120 in the bore 112 away from the sleeve 140 to expose the profile 146 in the sleeve 140. Further details of this operation are discussed below. Subsequently, when a frac dart is pumped downhole, the frac dart locates on the profile 146 of the sleeve 140 so that frac operations can proceed.
  • Figs. 8A-8F show the indexing sleeve 100 of Figs. 7A-7C in various stages of operation. Many of the same operational steps would apply to the other indexing sleeves disclosed herein.
  • the indexing sleeve 100 deploys downhole in a closed condition with the sleeve 140 covering the port 112 and with the insert 120 covering the profile 146 on the sleeve 140.
  • a dropped plug 170 can pass through the indexing sleeve 100.
  • the dropped plug 170 engages the springs 135, and the sensor 134 and control circuitry 131 detects and counts the passage of the plug 170. This process of dropped plugs 170 and counting is repeated until the preset number of plugs 170 has passed through the indexing sleeve 100.
  • the control circuitry 131 activates the valve 136, which removes the restraining arm or pin 139 from the insert 120. Now free, the insert 120 moves by the bias of the spring 125 way from the sleeve 140, thereby exposing the sleeve's profile 146.
  • the plug is a frac dart 180 similar to that described previously with reference to Fig. 6 .
  • the dart 180 reaches the exposed profile 146 on the sleeve 140.
  • the biased keys 186 on the dart 180 extend outward and engage or catch the profile 146.
  • the keys 156 have a notch locking in the profile 146 in only a first direction tending to open the sleeve 140. The rest of the key 186, however, allows the dart 180 move in a second direction opposite to the first direction so it can be produced to the surface as discussed later.
  • the dart's seal 182 seals inside an interior passage or seat in the sleeve 140. Because the dart 180 is passing through the sleeve 140, interaction of the seal 182 with the surrounding sleeve 140 can tend to slow the dart's passage. This helps the keys 186 to catch in the exposed profile 146.
  • Fig. 8E After the zones having been stimulated, operators open the well to production by opening any downhole control valve or the like. Because the dart 180 has a particular specific gravity (e.g., about 1.4 or so), production fluid coming up the tubing and housing bore 102 as shown in Fig. 8E brings the dart 180 back to the surface. If for any reason, the dart 180 does not come to the surface, then the dart 180 can be milled. Finally, as shown in Fig. 8F , the well can be produced through the open sleeve 100 without restriction or intervention. At any point, the indexing sleeve 100 can be manually reset closed by using an appropriate tool.
  • the indexing sleeve 100 can be manually reset closed by using an appropriate tool.
  • energizing the insert 120 in the indexing sleeve 100 can use a number of arrangements.
  • the actuator 130 uses a piston effect as a chamber fills with pressure and moves the insert 120.
  • the actuator 130 uses a solenoid and pin arrangement to release the sleeve 120 biased by the spring 122.
  • Other ways to energize the insert 120 can be used, including, hydrostatic chambers, motors, and the like.
  • a solder plug could be melted to allow movement between two axial members.
  • indexing sleeves 100 of Figs. 2 , 5A-5C , and 7A-7C used profiles 146 on the sleeves 140, while the frac darts 160/180 of Figs. 3 and 6 used biased keys 186 to catch on the profiles 146 when exposed.
  • a reverse arrangement can be used.
  • an indexing sleeve 100 has many of the same components as the previous embodiments so that like reference numerals are used.
  • the sleeve 140 has a plurality of keys or dogs 148 disposed in surrounding slots in the sleeve 140. Springs or other biasing members 149 bias these dogs 148 through these slots toward the interior of the sleeve 140 where a frac plug passes.
  • these keys 148 remain retracted in the sleeve 140 so that plugs or frac darts can pass as desired.
  • the insert 120 has been activated by one of the darts or other plugs and has moved (downward) in the indexing sleeve 100, the insert's distal end 122 disengages from the keys 148. This allows the springs 149 to bias the keys 148 outward into the bore 102 of the sleeve 100.
  • the next frac dart 190 of Fig. 10 will engage the keys 148.
  • Fig. 10 shows a frac dart 190 having a seal 192 and a profile 196.
  • the dart 190 meets up to the sleeve 140, and the extended keys 148 catch in the dart's exposed profile 196.
  • fluid pressure applied against the caught dart 190 can move the sleeve 140 (downward) in the indexing sleeve 100 to open the housing's ports 112.
  • indexing sleeves 100 and darts 160/180/190 have keys and profiles for engagement inside the indexing sleeves 100.
  • an indexing sleeve 100 shown in Fig. 11A-11D uses a plug in the form of a ball 170 for engagement inside the indexing sleeve 100. Again, this indexing sleeve 100 has many of the same components as the previous embodiment so that like reference numerals are used.
  • the sleeve 140 has a plurality of keys or dogs 148 disposed in surrounding slots in the sleeve 140. Springs or other biasing members 149 bias these dogs 148 through these slots toward the interior of the sleeve 140.
  • the keys 148 remain retracted as shown in Fig. 11A-11B .
  • the insert's distal end 124 disengages from the keys 148.
  • the distal end 124 shown in Figs. 11A-11B initially covers the keys 148 and exposes them once the insert 120 moves as shown in Figs. 11C-11D .
  • the springs 149 bias the keys 148 outward into the bore 102.
  • the next ball 170 will engage the extended keys 148.
  • the end-section in Fig. 11B shows how the distal end 124 of the insert 120 can hold the keys 148 retracted in the sleeve 140, allowing for passage of balls 170 through the larger diameter D.
  • the end-section in Fig. 11D shows how the extend keys 148 create a seat with a restricted diameter d to catch a ball 170.
  • the keys 148 can be used, although any suitable number could be used.
  • the proximate ends of the keys 148 can have shoulders to catch inside the sleeve's slots to prevent the keys 148 from passing out of these slots.
  • the keys 148 when extended can be configured to have 1/8-inch interference fit to engage a corresponding plug ( e.g ., ball 170).
  • the tolerance can depend on a number of factors.
  • the indexing sleeve 100 can have two inserts (e.g ., insert 120 and sleeve 140).
  • the sleeve 140 has a catch 146 and can move relative to ports 112 to allow fluid communication between the sleeve's bore 102 and the annulus. Because the insert 120 moves in the housing 110 by the actuator 130, the insert 120 may instead cover a port in the housing 110 for fluid communication. Thus, once the insert 120 is moved, the indexing sleeve 100 can be opened.
  • indexing sleeve 100 has a housing 110, ports 112, an insert 120, and other components similar to those disclosed previously.
  • This indexing sleeve 100 lacks a second insert or sleeve ( e.g ., 140) as in previous embodiments. Instead, the catch ( i.e ., profile 126 or other locking shoulder) is defined in the bore 102 of the housing 110.
  • a passing dart 180 or other plug interacts with the spring 135 and sensor arrangement 134 or other components of the actuator 130, which moves the insert 120 as discussed previous.
  • the insert 120 When the insert 120 is moved by the actuator 130, it reveals the ports 112 in the housing 110 as shown in Figure 12B so that the bore 102 communicates with the annulus.
  • movement of the insert 120 exposes this fixed catch 126.
  • the next dropped dart 180 or plug can engage the catch 126 in the bore 102 to close off the lower portion of the tubing string.
  • using this form of indexing sleeve 100 may be advantageous for operators.
  • indexing sleeves and plugs disclosed herein can be used in conjunction with or substituted for the other indexing sleeves, plugs, and arrangements disclosed in co-pending application Ser. No. 12/753,331 , which has been incorporated herein by reference.
  • a plug can be a dart, a ball, or any other comparable item for dropping down a tubing string and landing in a sliding sleeve. Accordingly, plug, dart, ball, or other such term can be used interchangeably herein when referring to such items.
  • the various indexing sleeves disclosed herein can be arranged with one another and with other sliding sleeves. It is possible, therefore, for one type of indexing sleeve and plug to be incorporated into a tubing string having another type of indexing sleeve and plug disclosed herein.

Landscapes

  • Life Sciences & Earth Sciences (AREA)
  • Engineering & Computer Science (AREA)
  • Geology (AREA)
  • Mining & Mineral Resources (AREA)
  • Physics & Mathematics (AREA)
  • Environmental & Geological Engineering (AREA)
  • Fluid Mechanics (AREA)
  • General Life Sciences & Earth Sciences (AREA)
  • Geochemistry & Mineralogy (AREA)
  • Quick-Acting Or Multi-Walled Pipe Joints (AREA)
  • Instruments For Viewing The Inside Of Hollow Bodies (AREA)

Claims (23)

  1. Un appareil de flux de fond de trou, comprenant :
    un corps d'outil (110) ayant un alésage (102) et se déployant en fond de trou sur une colonne de production (12) ;
    un cliquet (140) disposé dans l'alésage, le cliquet (140) ayant une condition inactive pour faire passer un bouchon (170, 180, 190) à travers l'alésage (102) et ayant une condition active pour se mettre en prise avec un bouchon (170, 180, 190) dans l'alésage (102) ;
    au moins un organe de flexion (135) disposé dans l'alésage (102) du corps d'outil (110), l'au moins un organe de flexion (135) pouvant être déplacé d'une condition non fléchie à une condition fléchie par mise en prise avec un bouchon (170, 180, 190) passant à travers l'alésage (102) du corps d'outil (110) ;
    un insert (120) disposé dans l'alésage (102) du corps d'outil (110) et pouvant être déplacé entre des première et deuxième positions par rapport au cliquet (140), l'insert (120) dans la première position mettant le cliquet (140) dans la condition inactive, l'insert (120) dans la deuxième position mettant le cliquet (140) dans la condition active ; et
    un actionneur (130) conçu pour être actionné en réponse au déplacement de l'au moins un organe de flexion (135) vers la condition fléchie, l'actionneur (130), lorsqu'il est actionné, déplaçant l'insert (120) de la première position à la deuxième position, mettant ainsi le cliquet dans la condition active.
  2. L'appareil de la revendication 1, dans lequel l'actionneur (130) déplace l'insert (120) de la première position à la deuxième position en réponse au fait qu'un nombre prédéfini de bouchons (170, 180, 190) déplacent l'organe de flexion (135) dans la condition fléchie.
  3. L'appareil de la revendication 1 ou la revendication 2, dans lequel l'insert (120) déplacé de la première position à la deuxième position ouvre un orifice (112) dans l'alésage (102) du corps d'outil (110).
  4. L'appareil de la revendication 1, la revendication 2, ou la revendication 3, dans lequel le cliquet (140) comprend un manchon disposé dans l'alésage (102) et pouvant être déplacé d'une condition fermée à une condition ouverte par rapport à un orifice (112) dans le corps d'outil (110), et dans lequel le manchon se déplace de la condition fermée à la condition ouverte en réponse à l'activation d'une pression de fluide contre un bouchon (170, 180, 190) en prise avec le cliquet (140).
  5. L'appareil de l'une quelconque des revendications 1 à 4, dans lequel le cliquet (140) comprend un profil (146) disposé dans l'alésage (102), le cliquet (140) dans la condition inactive étant couvert par une partie de l'insert (120) dans la première position, le cliquet (140) dans la condition active étant exposé dans l'alésage (102), le profil (146) dans la condition active pouvant être mis en prise par au moins une clé polarisée (186) disposée sur un bouchon (180) pouvant être déployé à travers l'alésage (102) lorsque le bouchon (180) passe ainsi.
  6. L'appareil de l'une quelconque des revendications 1 à 4, dans lequel le cliquet (140) comprend au moins une clé polarisée (148) disposée dans l'alésage (102), l'au moins une clé polarisée (148) dans la condition inactive étant rétractée du passage intérieur par une partie de l'insert (120) dans la première position, l'au moins une clé polarisée (148) dans la condition active étant étendue dans l'alésage (102) et pouvant être mise en prise par un bouchon (170, 190) pouvant être déployé à travers l'alésage (102) lorsque le bouchon (170, 190) passe ainsi.
  7. L'appareil de l'une quelconque des revendications 1 à 6,
    dans lequel l'actionneur (130) comprend un capteur (134) sensible à la proximité d'une partie de l'au moins un organe de flexion (135) dans la condition fléchie, ou dans lequel l'actionneur (130) comprend un capteur à effet Hall sensible au matériau de l'au moins un organe de flexion (135).
  8. L'appareil de l'une quelconque des revendications 1 à 7, dans lequel l'actionneur (130) comprend un compteur (133) comptant un nombre des conditions fléchies de l'au moins un organe de flexion (135), l'actionneur (130) déplaçant l'insert (120) lorsque le nombre compté atteint un nombre prédéterminé.
  9. L'appareil de l'une quelconque des revendications 1 à 8, dans lequel l'au moins un organe de flexion (135) comprend une pluralité de ressorts disposés dans l'alésage (102) du corps d'outil (110), chacun des ressorts ayant une extrémité fixée dans l'alésage (102) et ayant une autre extrémité libre de se déplacer dans l'alésage (102).
  10. L'appareil de l'une quelconque des revendications 1 à 9,
    dans lequel l'actionneur (130) ouvre une communication fluidique à travers un orifice (118) dans le corps d'outil (110), l'insert (120) pouvant être déplacé de la première position à la deuxième position en réponse à une pression de fluide communiquée à travers l'orifice (118) lorsqu'il est ouvert ; ou
    dans lequel l'actionneur (130) comprend une vanne (136) ouvrant une communication fluidique à travers l'orifice (118) ; ou
    dans lequel l'actionneur (130) comprend un solénoïde ayant un plongeur (138) pouvant être déplacé par rapport à l'orifice (118).
  11. L'appareil de l'une quelconque des revendications 1 à 9,
    dans lequel un élément de sollicitation (125) sollicite l'insert (120) de la première position à la deuxième position et dans lequel l'actionneur (130) libère de façon sélective l'insert (120) de la première position ; ou
    dans lequel l'actionneur (130) comprend une broche (139) pouvant être déplacé par rapport à l'insert (120) d'une condition en prise à une condition désengagée, la broche (139) dans la condition désengagée libérant l'insert (120) de la première position ; ou
    dans lequel l'actionneur (130) comprend un solénoïde (136) déplaçant la broche (139) par rapport à l'insert (120).
  12. Un procédé de fonctionnement d'un manchon coulissant (100), le manchon coulissant (100) comprenant :
    un cliquet (140) disposé dans un alésage (102) du manchon coulissant (100), le cliquet (140) ayant une condition inactive pour faire passer un bouchon (170, 180, 190) à travers l'alésage (102) et ayant une condition active pour se mettre en prise avec un bouchon (170, 180, 190) dans l'alésage (102) ;
    au moins un organe de flexion (135) disposé dans l'alésage (102), l'au moins un organe de flexion (135) pouvant être déplacé d'une condition non fléchie à une condition fléchie par mise en prise avec un bouchon (170, 180, 190) passant à travers l'alésage (102) ;
    un insert (120) disposé dans l'alésage (102) et pouvant être déplacé entre des première et deuxième positions par rapport au cliquet (140), l'insert (120) dans la première position mettant le cliquet (140) dans la condition inactive, l'insert (120) dans la deuxième position mettant le cliquet (140) dans la condition active ; et
    un actionneur (130) étant actionné en réponse au déplacement de l'au moins un organe de flexion (135) vers la condition fléchie, l'actionneur (130) lorsqu'il est actionné déplaçant l'insert (120) de la première position à la deuxième position, mettant ainsi le cliquet dans la condition active,
    le procédé comprenant :
    le fait de déployer le manchon coulissant (100) en fond de trou sur une colonne de production (12) ;
    le fait de déployer au moins un premier bouchon (170, 180, 190) vers le bas de la colonne de production (12) par rapport au manchon coulissant (100) ;
    la fait de fléchir l'organe de flexion (135) disposé dans l'alésage (102) du manchon coulissant (100) en mettant en prise l'au moins un premier bouchon (170, 180, 190) contre l'organe de flexion (135) ;
    le fait d'activer l'actionneur (130) du manchon coulissant (100) par détection de la flexion de l'organe de flexion (135) avec l'actionneur (130) ;
    le fait de déplacer l'insert (120) avec l'actionneur activé (130) ; et
    le fait de changer le cliquet (140) de la condition inactive à la condition active en réponse au déplacement de l'insert (120), le cliquet (140) dans la condition active pour se mettre en prise avec un deuxième bouchon (170, 180, 190) étant déployé vers le bas de la colonne de production (12).
  13. Le procédé de la revendication 12, dans lequel la détection de la flexion de l'organe de flexion (135) avec l'actionneur (130) du manchon coulissant (100) comprend le fait de détecter la proximité d'une partie de l'organe de flexion (135) dans la condition fléchie par rapport à un capteur (134).
  14. Le procédé de la revendication 12 ou la revendication 13, comprenant en outre le fait de faire passer l'au moins un premier bouchon (170, 180, 190) au-delà du manchon coulissant (100) jusqu'à un ou plusieurs autres manchons coulissants (100) disposés plus loin en fond de trou sur la colonne de production (12).
  15. Le procédé de l'une quelconque des revendications 12 à 14, comprenant en outre le fait d'ouvrir un orifice (112) sur le manchon coulissant (100) en réponse au déplacement de l'insert (120).
  16. Le procédé de l'une quelconque des revendications 12 à 15, le procédé comprenant en outre :
    le fait de mettre en prise le deuxième bouchon (170, 180, 190) dans le cliquet (140) changé en condition active.
  17. Le procédé de la revendication 16, dans lequel le fait de mettre en prise le deuxième bouchon (170, 180, 190) dans le cliquet (140) comprend le fait de mettre en prise un profil (146) du cliquet (140) avec une clé polarisée (186) du deuxième bouchon (180).
  18. Le procédé de la revendication 16, dans lequel le fait de mettre en prise le deuxième bouchon (170, 180, 190) dans le cliquet (140) comprend le fait de mettre en prise un profil du deuxième bouchon (170, 190) avec une clé polarisée (148) du cliquet (140).
  19. Le procédé de la revendication 16 ou la revendication 18, comprenant en outre : le fait d'ouvrir une communication fluidique à partir de l'alésage (102) à travers un orifice (112) dans le manchon coulissant (100) en déplaçant un manchon (140), avec application d'une pression de fluide contre le deuxième bouchon (170, 180, 190) en prise dans le cliquet (140), par rapport à un orifice (112).
  20. Le procédé de l'une quelconque des revendications 12 à 19, dans lequel le fait de détecter la flexion de l'organe de flexion (135) comprend :
    le fait de détecter un nombre prédéfini de l'au moins un des premiers bouchons (170, 180, 190) fléchissant l'organe de flexion (135) dans une condition fléchie.
  21. Le procédé de la revendication 20 dans lequel le fait de détecter la flexion de l'organe de flexion (135) comprend de plus le fait de compter un nombre des conditions fléchies de l'organe de flexion (135) et le fait d'actionner l'actionneur pour déplacer l'insert (120) lorsque le nombre compté atteint le nombre prédéfini.
  22. Le procédé de l'une quelconque des revendications 12 à 21, dans lequel le fait de déplacer l'insert (120) avec l'actionneur activé (130) comprend le fait d'ouvrir une communication fluidique à travers un orifice (112) dans le manchon coulissant (100) et de déplacer l'insert (120) en réponse à une pression de fluide communiquée à partir de l'orifice (112) lorsqu'il est ouvert.
  23. Le procédé de l'une quelconque des revendications 12 à 21, dans lequel le fait de déplacer l'insert (120) avec l'actionneur activé (130) comprend le fait de solliciter l'insert (120) et de libérer de façon sélective l'insert sollicité (120) pour qu'il se déplace.
EP12151459.0A 2011-02-07 2012-01-17 Manche d'indexation pour fracturation multi-niveaux en une seule manoeuvre Not-in-force EP2484862B1 (fr)

Applications Claiming Priority (1)

Application Number Priority Date Filing Date Title
US13/022,504 US8403068B2 (en) 2010-04-02 2011-02-07 Indexing sleeve for single-trip, multi-stage fracing

Publications (3)

Publication Number Publication Date
EP2484862A2 EP2484862A2 (fr) 2012-08-08
EP2484862A3 EP2484862A3 (fr) 2014-02-26
EP2484862B1 true EP2484862B1 (fr) 2018-04-11

Family

ID=45507528

Family Applications (1)

Application Number Title Priority Date Filing Date
EP12151459.0A Not-in-force EP2484862B1 (fr) 2011-02-07 2012-01-17 Manche d'indexation pour fracturation multi-niveaux en une seule manoeuvre

Country Status (4)

Country Link
EP (1) EP2484862B1 (fr)
AU (1) AU2012200380B2 (fr)
CA (1) CA2764764C (fr)
RU (1) RU2495994C1 (fr)

Families Citing this family (23)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US8668012B2 (en) 2011-02-10 2014-03-11 Halliburton Energy Services, Inc. System and method for servicing a wellbore
US8695710B2 (en) 2011-02-10 2014-04-15 Halliburton Energy Services, Inc. Method for individually servicing a plurality of zones of a subterranean formation
US8789600B2 (en) * 2010-08-24 2014-07-29 Baker Hughes Incorporated Fracing system and method
US8893811B2 (en) 2011-06-08 2014-11-25 Halliburton Energy Services, Inc. Responsively activated wellbore stimulation assemblies and methods of using the same
US8899334B2 (en) 2011-08-23 2014-12-02 Halliburton Energy Services, Inc. System and method for servicing a wellbore
US8991509B2 (en) 2012-04-30 2015-03-31 Halliburton Energy Services, Inc. Delayed activation activatable stimulation assembly
US9784070B2 (en) 2012-06-29 2017-10-10 Halliburton Energy Services, Inc. System and method for servicing a wellbore
EP2708694A1 (fr) 2012-09-14 2014-03-19 Welltec A/S Dispositif de chute
CN103969062B (zh) * 2013-01-25 2016-09-07 深圳市弗赛特科技股份有限公司 井下工具高压综合试验井筒
US9587486B2 (en) * 2013-02-28 2017-03-07 Halliburton Energy Services, Inc. Method and apparatus for magnetic pulse signature actuation
NO3044084T3 (fr) 2013-12-04 2018-04-14
EP3097257A4 (fr) * 2014-01-24 2017-09-27 Completions Research AG Système de fracturation à haute pression à multiples étages avec système de comptage
RU2555989C1 (ru) * 2014-05-12 2015-07-10 Акционерное общество "Новомет-Пермь" Муфта для многостадийного гидроразрыва пласта
EP3158162B1 (fr) * 2014-06-23 2020-08-26 Welltec Oilfield Solutions AG Système de stimulation de fond de trou
US9587464B2 (en) * 2014-10-02 2017-03-07 Sc Asset Corporation Multi-stage liner with cluster valves and method of use
DK3018285T3 (en) 2014-11-07 2019-04-08 Weatherford Tech Holdings Llc INDEXING STIMULATING SLEEVES AND OTHER Borehole Tools
US10337288B2 (en) * 2015-06-10 2019-07-02 Weatherford Technology Holdings, Llc Sliding sleeve having indexing mechanism and expandable sleeve
GB2553834A (en) 2016-09-16 2018-03-21 Schoeller Bleckmann Oilfield Equipment Ag Splitflow valve
CN109441419B (zh) * 2018-10-15 2020-12-04 中石化石油工程技术服务有限公司 一种油气储层二次改造管柱
CA3104454A1 (fr) * 2019-01-24 2020-07-30 The Wellboss Company, Inc. Outil de manchon de fond de trou
CN111997563B (zh) * 2020-08-04 2022-06-24 中国石油化工股份有限公司 一种泵封一体找堵水管柱及其游动底堵
CN114427418B (zh) * 2020-09-25 2023-12-01 中国石油化工股份有限公司 一种不限级全通径分段压裂滑套的专用开关工具
CN113356794B (zh) * 2021-06-04 2021-12-07 西南石油大学 全通径无限级的智能开关滑套

Family Cites Families (11)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US4907649A (en) * 1987-05-15 1990-03-13 Bode Robert E Restriction subs for setting cement plugs in wells
SU1656116A1 (ru) * 1988-07-14 1991-06-15 Всесоюзный Научно-Исследовательский Институт Буровой Техники Гидравлический пакер
US6041857A (en) 1997-02-14 2000-03-28 Baker Hughes Incorporated Motor drive actuator for downhole flow control devices
US6491097B1 (en) * 2000-12-14 2002-12-10 Halliburton Energy Services, Inc. Abrasive slurry delivery apparatus and methods of using same
US6601648B2 (en) * 2001-10-22 2003-08-05 Charles D. Ebinger Well completion method
US7387165B2 (en) 2004-12-14 2008-06-17 Schlumberger Technology Corporation System for completing multiple well intervals
RU58601U1 (ru) * 2006-06-22 2006-11-27 Открытое акционерное общество "Татнефть" им. В.Д. Шашина Устройство для цементирования обсадной колонны в скважине
US7661478B2 (en) * 2006-10-19 2010-02-16 Baker Hughes Incorporated Ball drop circulation valve
US20090308588A1 (en) * 2008-06-16 2009-12-17 Halliburton Energy Services, Inc. Method and Apparatus for Exposing a Servicing Apparatus to Multiple Formation Zones
US8261761B2 (en) * 2009-05-07 2012-09-11 Baker Hughes Incorporated Selectively movable seat arrangement and method
WO2010127457A1 (fr) * 2009-05-07 2010-11-11 Packers Plus Energy Services Inc. Raccord double femelle de manchon coulissant et procédé et appareil de traitement de fluide de puits de forage

Non-Patent Citations (1)

* Cited by examiner, † Cited by third party
Title
None *

Also Published As

Publication number Publication date
CA2764764A1 (fr) 2012-08-07
AU2012200380B2 (en) 2013-11-21
RU2012103975A (ru) 2013-08-20
CA2764764C (fr) 2016-01-12
EP2484862A2 (fr) 2012-08-08
RU2495994C1 (ru) 2013-10-20
EP2484862A3 (fr) 2014-02-26
AU2012200380A1 (en) 2012-02-16

Similar Documents

Publication Publication Date Title
EP2484862B1 (fr) Manche d'indexation pour fracturation multi-niveaux en une seule manoeuvre
US8403068B2 (en) Indexing sleeve for single-trip, multi-stage fracing
EP2372080B1 (fr) Manchon d'indexation pour fracturation multi-niveaux en une seule manoeuvre
US10392899B2 (en) Indexing stimulating sleeve and other downhole tools
US10082002B2 (en) Multi-stage fracturing with smart frack sleeves while leaving a full flow bore
EP2834456B1 (fr) Procede d'actionnement d'outile de puits de forage
EP2559845B1 (fr) Système de stimulation multi-réseau à haut débit
US8991505B2 (en) Downhole tools and methods for selectively accessing a tubular annulus of a wellbore
EP2829684B1 (fr) Appareil de traitement de puits de forage multi-ensemble à chevauchement déclenché électroniquement
CA3002367A1 (fr) Systeme de fracturation dote d'orifices decales de cable metallique et systeme de surveillance electronique en temps reel
WO2014082054A1 (fr) Système de complétion, de stimulation et de production
US9428977B2 (en) Multi-stage locking system for selective release of a potential energy force to set a subterranean tool
WO2017015214A1 (fr) Procédé de fermeture de soupape d'arrêt pour la stimulation multi-zone sans lignes d'intervention ou de commande à partir de la surface

Legal Events

Date Code Title Description
PUAI Public reference made under article 153(3) epc to a published international application that has entered the european phase

Free format text: ORIGINAL CODE: 0009012

AK Designated contracting states

Kind code of ref document: A2

Designated state(s): AL AT BE BG CH CY CZ DE DK EE ES FI FR GB GR HR HU IE IS IT LI LT LU LV MC MK MT NL NO PL PT RO RS SE SI SK SM TR

AX Request for extension of the european patent

Extension state: BA ME

RIC1 Information provided on ipc code assigned before grant

Ipc: E21B 34/14 20060101AFI20131001BHEP

PUAL Search report despatched

Free format text: ORIGINAL CODE: 0009013

AK Designated contracting states

Kind code of ref document: A3

Designated state(s): AL AT BE BG CH CY CZ DE DK EE ES FI FR GB GR HR HU IE IS IT LI LT LU LV MC MK MT NL NO PL PT RO RS SE SI SK SM TR

AX Request for extension of the european patent

Extension state: BA ME

RIC1 Information provided on ipc code assigned before grant

Ipc: E21B 34/14 20060101AFI20140121BHEP

17P Request for examination filed

Effective date: 20140818

RBV Designated contracting states (corrected)

Designated state(s): AL AT BE BG CH CY CZ DE DK EE ES FI FR GB GR HR HU IE IS IT LI LT LU LV MC MK MT NL NO PL PT RO RS SE SI SK SM TR

RAP1 Party data changed (applicant data changed or rights of an application transferred)

Owner name: WEATHERFORD TECHNOLOGY HOLDINGS, LLC

STAA Information on the status of an ep patent application or granted ep patent

Free format text: STATUS: EXAMINATION IS IN PROGRESS

17Q First examination report despatched

Effective date: 20170328

GRAP Despatch of communication of intention to grant a patent

Free format text: ORIGINAL CODE: EPIDOSNIGR1

STAA Information on the status of an ep patent application or granted ep patent

Free format text: STATUS: GRANT OF PATENT IS INTENDED

INTG Intention to grant announced

Effective date: 20171117

RIN1 Information on inventor provided before grant (corrected)

Inventor name: ROBISON, CLARK E.

Inventor name: MALLOY, ROBERT

Inventor name: COON, ROBERT

GRAS Grant fee paid

Free format text: ORIGINAL CODE: EPIDOSNIGR3

GRAA (expected) grant

Free format text: ORIGINAL CODE: 0009210

STAA Information on the status of an ep patent application or granted ep patent

Free format text: STATUS: THE PATENT HAS BEEN GRANTED

AK Designated contracting states

Kind code of ref document: B1

Designated state(s): AL AT BE BG CH CY CZ DE DK EE ES FI FR GB GR HR HU IE IS IT LI LT LU LV MC MK MT NL NO PL PT RO RS SE SI SK SM TR

REG Reference to a national code

Ref country code: GB

Ref legal event code: FG4D

REG Reference to a national code

Ref country code: CH

Ref legal event code: EP

REG Reference to a national code

Ref country code: AT

Ref legal event code: REF

Ref document number: 988233

Country of ref document: AT

Kind code of ref document: T

Effective date: 20180415

REG Reference to a national code

Ref country code: IE

Ref legal event code: FG4D

REG Reference to a national code

Ref country code: DE

Ref legal event code: R096

Ref document number: 602012044948

Country of ref document: DE

REG Reference to a national code

Ref country code: NL

Ref legal event code: MP

Effective date: 20180411

REG Reference to a national code

Ref country code: LT

Ref legal event code: MG4D

REG Reference to a national code

Ref country code: NO

Ref legal event code: T2

Effective date: 20180411

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: NL

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20180411

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: AL

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20180411

Ref country code: BG

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20180711

Ref country code: FI

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20180411

Ref country code: LT

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20180411

Ref country code: PL

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20180411

Ref country code: SE

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20180411

Ref country code: ES

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20180411

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: HR

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20180411

Ref country code: GR

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20180712

Ref country code: LV

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20180411

Ref country code: RS

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20180411

REG Reference to a national code

Ref country code: AT

Ref legal event code: MK05

Ref document number: 988233

Country of ref document: AT

Kind code of ref document: T

Effective date: 20180411

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: PT

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20180813

REG Reference to a national code

Ref country code: DE

Ref legal event code: R097

Ref document number: 602012044948

Country of ref document: DE

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: EE

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20180411

Ref country code: CZ

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20180411

Ref country code: RO

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20180411

Ref country code: AT

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20180411

Ref country code: DK

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20180411

Ref country code: SK

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20180411

PLBE No opposition filed within time limit

Free format text: ORIGINAL CODE: 0009261

STAA Information on the status of an ep patent application or granted ep patent

Free format text: STATUS: NO OPPOSITION FILED WITHIN TIME LIMIT

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: IT

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20180411

Ref country code: SM

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20180411

26N No opposition filed

Effective date: 20190114

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: SI

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20180411

REG Reference to a national code

Ref country code: DE

Ref legal event code: R119

Ref document number: 602012044948

Country of ref document: DE

REG Reference to a national code

Ref country code: NO

Ref legal event code: MMEP

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: MC

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20180411

REG Reference to a national code

Ref country code: CH

Ref legal event code: PL

GBPC Gb: european patent ceased through non-payment of renewal fee

Effective date: 20190117

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: LU

Free format text: LAPSE BECAUSE OF NON-PAYMENT OF DUE FEES

Effective date: 20190117

REG Reference to a national code

Ref country code: BE

Ref legal event code: MM

Effective date: 20190131

REG Reference to a national code

Ref country code: IE

Ref legal event code: MM4A

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: NO

Free format text: LAPSE BECAUSE OF NON-PAYMENT OF DUE FEES

Effective date: 20190131

Ref country code: DE

Free format text: LAPSE BECAUSE OF NON-PAYMENT OF DUE FEES

Effective date: 20190801

Ref country code: FR

Free format text: LAPSE BECAUSE OF NON-PAYMENT OF DUE FEES

Effective date: 20190131

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: BE

Free format text: LAPSE BECAUSE OF NON-PAYMENT OF DUE FEES

Effective date: 20190131

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: LI

Free format text: LAPSE BECAUSE OF NON-PAYMENT OF DUE FEES

Effective date: 20190131

Ref country code: GB

Free format text: LAPSE BECAUSE OF NON-PAYMENT OF DUE FEES

Effective date: 20190117

Ref country code: CH

Free format text: LAPSE BECAUSE OF NON-PAYMENT OF DUE FEES

Effective date: 20190131

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: IE

Free format text: LAPSE BECAUSE OF NON-PAYMENT OF DUE FEES

Effective date: 20190117

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: TR

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20180411

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: MT

Free format text: LAPSE BECAUSE OF NON-PAYMENT OF DUE FEES

Effective date: 20190117

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: CY

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20180411

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: IS

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20180811

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: HU

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT; INVALID AB INITIO

Effective date: 20120117

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: MK

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20180411