WO2005001240A1 - Plug and expel flow control device - Google Patents

Plug and expel flow control device Download PDF

Info

Publication number
WO2005001240A1
WO2005001240A1 PCT/US2004/018756 US2004018756W WO2005001240A1 WO 2005001240 A1 WO2005001240 A1 WO 2005001240A1 US 2004018756 W US2004018756 W US 2004018756W WO 2005001240 A1 WO2005001240 A1 WO 2005001240A1
Authority
WO
WIPO (PCT)
Prior art keywords
flow control
control device
shell
plug member
tubing string
Prior art date
Application number
PCT/US2004/018756
Other languages
French (fr)
Inventor
Graham E. Farquhar
Original Assignee
Baker Hughes Incorporated
Priority date (The priority date is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the date listed.)
Filing date
Publication date
Application filed by Baker Hughes Incorporated filed Critical Baker Hughes Incorporated
Priority to AU2004252506A priority Critical patent/AU2004252506B2/en
Publication of WO2005001240A1 publication Critical patent/WO2005001240A1/en
Priority to NO20060107A priority patent/NO338390B1/en

Links

Classifications

    • E—FIXED CONSTRUCTIONS
    • E21—EARTH DRILLING; MINING
    • E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B47/00—Survey of boreholes or wells
    • E21B47/10—Locating fluid leaks, intrusions or movements
    • E21B47/117—Detecting leaks, e.g. from tubing, by pressure testing
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH DRILLING; MINING
    • E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B33/00—Sealing or packing boreholes or wells
    • E21B33/10—Sealing or packing boreholes or wells in the borehole
    • E21B33/12—Packers; Plugs

Definitions

  • the invention relates generally to flow control devices for establishing temporary obstructions within a tubing string.
  • the invention also relates to devices and methods for pressure testing of production tubing within a hydrocarbon production well or for operating hydraulic tools within a tubing string.
  • -l- describes a rupture disk arrangement wherein a rupture disk, typically formed of nickel, is incorporated into the tubing string prior to running the tubing string into the wellbore.
  • This type of device is also known commercially as a "well test membrane.”
  • This arrangement is unsatisfactory for some purposes since it does not allow passage of fluid or tools through the tubing string while the tubing string is being tripped into the wellbore. The intact rupture disk prevents such passage.
  • the Model E Hydro Trip pressure sub by Baker Oil Tools, is another flow control device that is used to establish a temporary blockage within a tubing string.
  • This device uses collet fingers to provide a restricted-diameter ball seat upon which a plugging ball is seated to establish a fluid blockage.
  • several shear screws are sheared, permitting a sleeve within the tubing string to slide downwardly within the flowbore so that the collet fingers can retract back into a matching recess in the flowbore wall, thereby allowing the plugging ball to fall into the well sump below and result in an unplugged condition.
  • This device may malfunction if the shear screws do not shear at the intended fluid pressure, or do not all shear at the same time, thereby causing the sliding sleeve to become stuck or to slide prematurely.
  • this arrangement can only be used a single time. Once the shear screws have been sheared, no other plugging ball will be supported upon the ball seat unless the tubing string is first removed from the wellbore and then reset. This, of course, is costly and time consuming.
  • a shear-out ball seat sub that provides a temporary blockage of a portion of the tubing string when a ball-shaped plug is dropped into a tubing string and then seated upon a seating arrangement that is provided by a frangible member. The blockage is later removed by shearing away a frangible member to allow the plug to drop into the well sump.
  • this type of arrangement can only be located at the lower end of the tubing string and no other points along the tubing string, thereby limiting its usefulness. This arrangement, of course, is also limited to a single use.
  • the invention provides devices and methods for fluid flow control within a production tubing string wherein a temporary flow blockage is established and selectively removed from the tubing string so that pressure testing or operation of a hydraulic tool within the string may be performed.
  • the flow control device does not require frangible members, such as shear screws to operate and may be reusable. Fluids and tools may be passed through the device as the device is tripped in.
  • the flow control device includes a housing that defines a flowbore therethrough with a restricted diameter portion.
  • the restricted diameter portion presents a seating surface for a plug member and is provided by an annular shell that is shaped to project convexly inwardly.
  • the shell may be fashioned of metal, elastomer or another suitable material, and it is capable of yielding to permit passage of a plug member upon application of a suitably great amount of fluid pressure.
  • a plugging member is dropped in to the tubing string from the surface of the well and seats upon the seating surface.
  • the tubing string is then pressured up to a first fluid pressure level for testing, tool operation, or the like, and the pressuring up will urge the plugging member against the plug seat in order to effect a fluid seal.
  • fluid pressure above the plugging member is raised to a second, overpressure level. The plug is then urged through the restricted diameter portion and expelled from the device to the wellbore sump below.
  • Figure 1 is a side, cross-sectional view of an exemplary wellbore having a production tubing string disposed therein which incorporates a plug and expel device constructed in accordance with the present invention.
  • Figure 2 is a side, cross-sectional view of an exemplary plug and expel device wherein the plugging member is shown seated for temporary obstruction of the tubing string.
  • Figure 2A is an axial cross-section taken along lines A-A in Figure 2.
  • Figure 3 is a side cross-sectional view of the exemplary plug and expel device shown in Figures 2 and 2A, now with the plugging member having been expelled from within.
  • Figure 3A is an axial cross-section taken along lines A-A in Figure 3.
  • FIG. 1 schematically illustrates an exemplary production well 10 having a wellbore 12 disposed through the earth 14 to a formation (not shown).
  • the wellbore 12 is cased by casing 16.
  • a production tubing string 18 is disposed within the wellbore 12 from the surface 20 of the well 10, in preparation for the production of hydrocarbons from the formation.
  • the production tubing string 18 is made up of a series of individual tubing sections 22, which are affixed to one another by threading, as is known in the art.
  • the tubing string 18 also includes a plug and expel device 24 that is constructed in accordance with the present invention.
  • the plug and expel device 24 includes a tubular outer sub, or housing, 26 having upper and lower axial ends 28, 30.
  • the ends 28, 30 of the sub 26 are threaded to allow the sub 26 to be incorporated into the tubing string 18 by threaded interconnection with neighboring tubing sections 22.
  • the sub 26 defines a fluid flowbore 32 axially therethrough. When the sub 26 is interconnected with neighboring tubing sections 22, the flowbore 32 is aligned with the fluid flowbores defined within those neighboring sections 22, thereby allowing fluids to pass through the production tubing string 18.
  • a restrictive throat is contained within the flowbore 32 and permits a plugging member, such as tripping ball 36, to be selectively seated thereupon to block fluid flow within the tubing string 18.
  • the restrictive throat 34 is formed by an annular convex shell, or membrane, 38 that protrudes inwardly from the walls of the flowbore 32 to provide a reduced diameter restriction within the flowbore 32.
  • the shell 38 is formed of a flexible material.
  • the shell 38 is non- rigid and capable of yielding, in an elastic or plastic manner, upon application of a predetermined force.
  • the shell 38 is formed of a metal alloy. Additionally, a plastic or composite compound having suitable resilience properties might be used to construct the shell 38.
  • the shell 38 is radially inwardly convex in shape and preferably encloses an annular fluid chamber 40.
  • the fluid chamber 40 is preferably filled with a fluid that assists in controlled yielding of the shell 38 and portions thereof. Suitable fluids for this application include nitrogen and water. Additionally, silicon type oil might be used.
  • Fill port 42 is disposed through the housing 26 to permit filling of the fluid chamber 40. Drain plug 44 is disposed within the fill port 42 to close it off when not in use.
  • the restrictive throat 34 may be an elastomeric bladder element that is inflated with fluid.
  • the shell 38 provides an annular seating surface 46 for receiving the tripping ball 36. While a spherical tripping ball 36 is shown in Figures 2 and 3, it should be understood by those of skill in the art that plugging members of other suitable shapes (such as cylindrical) might be used as well, so long as a suitable fluid seal will be formed with the seating surface 46 when fluid pressure is applied to the ball 36.
  • the plug and expel device 24 is integrated into the string of production tubing 18 and then run into the wellbore 12. Fluids and tools are able to pass through the tubing string 18 and the flowbore 32 of the plug and expel device 24, as necessary.
  • the tubing string 18 can be prepared for testing by dropping the tripping ball 36, or other suitable plugging member, into the tubing string 18 from the surface 20. The ball 36 will become seated upon the seating surface 46. The tubing string 18 may then be pressure tested by increasing fluid pressure within the tubing string 18 at the surface and, as a result, above the ball 36.
  • the fluid pressure is increased only to a first level, which is suitable for pressure testing the tubing string 18 but not sufficient to dislodge the ball 36 from the restricted throat portion 34 of the flow control device 24.
  • a first level which is suitable for pressure testing the tubing string 18 but not sufficient to dislodge the ball 36 from the restricted throat portion 34 of the flow control device 24.
  • the pressure might also be increased within the tubing string 18 in order to operate a hydraulic tool, inflate a packer, or the like.
  • the tripping ball 36 Upon application of a predetermined overpressure, the tripping ball 36 will be urged through the restricted throat portion 34 and fall into the sump (not shown) at the bottom of the well 10.
  • the shell 38 is elastically deformed by the tripping ball 36 and portions of the shell 38 will yield by moving radially outwardly to accommodate passage of the ball 36.
  • the ball 36 is thereby expelled from the flow control device 24 and will then drop into the sump (not shown) at the bottom of the wellbore 12.
  • the flow control device 24 may also be reused after the ball 36 has been expelled from the restricted throat 34 since the shell 38 will tend to return to its undeformed shape, thereby again presenting the seating surface 46 for a second tripping ball 36 to be landed thereupon.
  • the second tripping ball 36 may be selectively expelled from the device 24 in the manner described previously.
  • the reuseable nature of the device 24 is highly advantageous since it permits, for example, pressure tests to be performed after some period of production operation.

Abstract

A flow control device include a housing that defines a flowbore therethrough with a restricted diameter portion. The restricted diameter portion presents a seating surface (46) for a plug member (36) and is provided by an annular shell (38) that is shaped to project convexly inwardly. The shell is capable of yielding to permit passage of a plug member (36) upon application of fluid pressure. When it is desired to remove the plugging member (36) from the tubing string (18), and reestablish fluid flow through the tubing string (18), fluid pressure above the plugging member (36) is raised to a second, overpressure level. The plug is then urged through the restricted diameter portion and expelled from the device to the wellbore sump below.

Description

PLUG AND EXPEL FLOW CONTROL DEVICE BACKGROUND OF THE INVENTION
1. Field of the Invention
[0001] The invention relates generally to flow control devices for establishing temporary obstructions within a tubing string. In certain aspects, the invention also relates to devices and methods for pressure testing of production tubing within a hydrocarbon production well or for operating hydraulic tools within a tubing string. 2. Description of the Related Art
[0002] After a production well is drilled, cased, and, if required perforated, a string of production tubing is run into the cased wellbore. Hydrocarbons from a downhole formation are then drawn into the production tubing, under impetus of a surface-based pump, and brought to the surface of the well. After the production tubing is run into the wellbore, it is desirable to test the pressure integrity of the tubing before drawing production fluid from the formation. Leaks in the production tubing string result in inefficient production and can be costly to repair after production has begun. [0003] In order to pressure test the production tubing, it is necessary to create a temporary plug or obstruction within the tubing string. Fluid is then introduced above the obstruction and pressurized so that any leakage can be detected. After testing, the obstruction must be removed from the tubing string. In other instances, it may be desirable to establish a temporary obstruction within the tubing string in order to actuate a hydraulic tool within the tubing string above the obstruction.
[0004] Unfortunately, current temporary plug flow control devices are problematic or
less than reliable in practice. U.S. Patent No. 5,996,696 issued to Jeffree et al.
-l- describes a rupture disk arrangement wherein a rupture disk, typically formed of nickel, is incorporated into the tubing string prior to running the tubing string into the wellbore. This type of device is also known commercially as a "well test membrane." This arrangement is unsatisfactory for some purposes since it does not allow passage of fluid or tools through the tubing string while the tubing string is being tripped into the wellbore. The intact rupture disk prevents such passage.
[0005] The Model E Hydro Trip pressure sub, by Baker Oil Tools, is another flow control device that is used to establish a temporary blockage within a tubing string. This device uses collet fingers to provide a restricted-diameter ball seat upon which a plugging ball is seated to establish a fluid blockage. Upon the application of a predetermined amount of pressure within the tubing string above the plugging ball, several shear screws are sheared, permitting a sleeve within the tubing string to slide downwardly within the flowbore so that the collet fingers can retract back into a matching recess in the flowbore wall, thereby allowing the plugging ball to fall into the well sump below and result in an unplugged condition. This device may malfunction if the shear screws do not shear at the intended fluid pressure, or do not all shear at the same time, thereby causing the sliding sleeve to become stuck or to slide prematurely. In addition, this arrangement can only be used a single time. Once the shear screws have been sheared, no other plugging ball will be supported upon the ball seat unless the tubing string is first removed from the wellbore and then reset. This, of course, is costly and time consuming.
[0006] Also known is a shear-out ball seat sub that provides a temporary blockage of a portion of the tubing string when a ball-shaped plug is dropped into a tubing string and then seated upon a seating arrangement that is provided by a frangible member. The blockage is later removed by shearing away a frangible member to allow the plug to drop into the well sump. Unfortunately, this type of arrangement can only be located at the lower end of the tubing string and no other points along the tubing string, thereby limiting its usefulness. This arrangement, of course, is also limited to a single use. [0007] The present invention addresses the problems of the prior art.
SUMMARY OF THE INVENTION
[0008] The invention provides devices and methods for fluid flow control within a production tubing string wherein a temporary flow blockage is established and selectively removed from the tubing string so that pressure testing or operation of a hydraulic tool within the string may be performed. The flow control device does not require frangible members, such as shear screws to operate and may be reusable. Fluids and tools may be passed through the device as the device is tripped in.
[0009] In an exemplary embodiment, the flow control device includes a housing that defines a flowbore therethrough with a restricted diameter portion. The restricted diameter portion presents a seating surface for a plug member and is provided by an annular shell that is shaped to project convexly inwardly. The shell may be fashioned of metal, elastomer or another suitable material, and it is capable of yielding to permit passage of a plug member upon application of a suitably great amount of fluid pressure. In operation, a plugging member is dropped in to the tubing string from the surface of the well and seats upon the seating surface. The tubing string is then pressured up to a first fluid pressure level for testing, tool operation, or the like, and the pressuring up will urge the plugging member against the plug seat in order to effect a fluid seal. [0010] When it is desired to remove the plugging member from the tubing string, and reestablish fluid flow through the tubing string, fluid pressure above the plugging member is raised to a second, overpressure level. The plug is then urged through the restricted diameter portion and expelled from the device to the wellbore sump below.
BRIEF DESCRIPTION OF THE DRAWINGS
[0011] Figure 1 is a side, cross-sectional view of an exemplary wellbore having a production tubing string disposed therein which incorporates a plug and expel device constructed in accordance with the present invention.
[0012] Figure 2 is a side, cross-sectional view of an exemplary plug and expel device wherein the plugging member is shown seated for temporary obstruction of the tubing string.
[0013] Figure 2A is an axial cross-section taken along lines A-A in Figure 2.
[0014] Figure 3 is a side cross-sectional view of the exemplary plug and expel device shown in Figures 2 and 2A, now with the plugging member having been expelled from within.
[0015] Figure 3A is an axial cross-section taken along lines A-A in Figure 3. DETAILED DESCRIPTION OF THE PREFERRED EMBODIMENTS
[0016] Figure 1 schematically illustrates an exemplary production well 10 having a wellbore 12 disposed through the earth 14 to a formation (not shown). The wellbore 12 is cased by casing 16. A production tubing string 18 is disposed within the wellbore 12 from the surface 20 of the well 10, in preparation for the production of hydrocarbons from the formation. [0017] The production tubing string 18 is made up of a series of individual tubing sections 22, which are affixed to one another by threading, as is known in the art. The tubing string 18 also includes a plug and expel device 24 that is constructed in accordance with the present invention.
[0018] The structure and operation of the plug and expel device 24 is better appreciated with reference to Figures 2, 2A, 3 and 3A. As shown there, the plug and expel device 24 includes a tubular outer sub, or housing, 26 having upper and lower axial ends 28, 30. The ends 28, 30 of the sub 26 are threaded to allow the sub 26 to be incorporated into the tubing string 18 by threaded interconnection with neighboring tubing sections 22. The sub 26 defines a fluid flowbore 32 axially therethrough. When the sub 26 is interconnected with neighboring tubing sections 22, the flowbore 32 is aligned with the fluid flowbores defined within those neighboring sections 22, thereby allowing fluids to pass through the production tubing string 18. A restrictive throat, generally shown at 34, is contained within the flowbore 32 and permits a plugging member, such as tripping ball 36, to be selectively seated thereupon to block fluid flow within the tubing string 18. The restrictive throat 34 is formed by an annular convex shell, or membrane, 38 that protrudes inwardly from the walls of the flowbore 32 to provide a reduced diameter restriction within the flowbore 32. In preferred embodiments, the shell 38 is formed of a flexible material. The shell 38 is non- rigid and capable of yielding, in an elastic or plastic manner, upon application of a predetermined force. In currently preferred embodiments, the shell 38 is formed of a metal alloy. Additionally, a plastic or composite compound having suitable resilience properties might be used to construct the shell 38. The shell 38 is radially inwardly convex in shape and preferably encloses an annular fluid chamber 40. In some embodiments, the fluid chamber 40 is preferably filled with a fluid that assists in controlled yielding of the shell 38 and portions thereof. Suitable fluids for this application include nitrogen and water. Additionally, silicon type oil might be used. Fill port 42 is disposed through the housing 26 to permit filling of the fluid chamber 40. Drain plug 44 is disposed within the fill port 42 to close it off when not in use. In another exemplary embodiment, the restrictive throat 34 may be an elastomeric bladder element that is inflated with fluid. [0019] The shell 38 is secured within the flowbore 32 by press fitting, such as cryogenic fitting, or by other methods known in the art. As is apparent from Figure 2, the shell 38 provides an annular seating surface 46 for receiving the tripping ball 36. While a spherical tripping ball 36 is shown in Figures 2 and 3, it should be understood by those of skill in the art that plugging members of other suitable shapes (such as cylindrical) might be used as well, so long as a suitable fluid seal will be formed with the seating surface 46 when fluid pressure is applied to the ball 36.
[0020] In operation, the plug and expel device 24 is integrated into the string of production tubing 18 and then run into the wellbore 12. Fluids and tools are able to pass through the tubing string 18 and the flowbore 32 of the plug and expel device 24, as necessary. Once the production tubing string 18 is run in so that the device 24 is disposed at a desired depth, the tubing string 18 can be prepared for testing by dropping the tripping ball 36, or other suitable plugging member, into the tubing string 18 from the surface 20. The ball 36 will become seated upon the seating surface 46. The tubing string 18 may then be pressure tested by increasing fluid pressure within the tubing string 18 at the surface and, as a result, above the ball 36. The fluid pressure is increased only to a first level, which is suitable for pressure testing the tubing string 18 but not sufficient to dislodge the ball 36 from the restricted throat portion 34 of the flow control device 24. Those of skill in the art will recognize that, in lieu of pressure testing of the tubing string 18, the pressure might also be increased within the tubing string 18 in order to operate a hydraulic tool, inflate a packer, or the like.
[0021] Upon application of a predetermined overpressure, the tripping ball 36 will be urged through the restricted throat portion 34 and fall into the sump (not shown) at the bottom of the well 10. The shell 38 is elastically deformed by the tripping ball 36 and portions of the shell 38 will yield by moving radially outwardly to accommodate passage of the ball 36. The ball 36 is thereby expelled from the flow control device 24 and will then drop into the sump (not shown) at the bottom of the wellbore 12. [0022] It is noted that the flow control device 24 may also be reused after the ball 36 has been expelled from the restricted throat 34 since the shell 38 will tend to return to its undeformed shape, thereby again presenting the seating surface 46 for a second tripping ball 36 to be landed thereupon. The second tripping ball 36 may be selectively expelled from the device 24 in the manner described previously. The reuseable nature of the device 24 is highly advantageous since it permits, for example, pressure tests to be performed after some period of production operation.
[0023] Those of skill in the art will recognize that numerous modifications and changes may be made to the exemplary designs and embodiments described herein and that the invention is limited only by the claims that follow and any equivalents thereof.

Claims

CLAIMSWhat is claimed is:
1. A flow control device for selectively closing a tubing string to fluid flow therethrough, the device comprising: a housing defining a flowbore therethrough; a radially inwardly projecting shell retained within the flowbore to provide a flowbore portion having restricted diameter, the shell presenting a plug member seat; a plug member shaped and sized to fit within the flowbore and be seated upon the plug member seat; and the shell being deformable to permit the plug member to pass through the restricted diameter upon application of a predetermined amount of force to the plug member.
2. The flow control device of claim 1 wherein the shell is elastically deformable.
3. The flow control device of claim 1 wherein the shell is plastically deformable.
4. The flow control device of claim 1 wherein the plug member is spherically shaped.
5. The flow control device of claim 1 wherein the shell is formed of metal.
6. The flow control device of claim 1 wherein the shell is formed of elastomer.
7. The flow control device of claim 1 wherein the shell is formed of plastic.
8. The flow control device of claim 1 wherein the shell is formed of a composite material.
9. The flow control device of claim 1 wherein the shell is annular.
10. The flow control device of claim 1 wherein the shell defines an annular fluid chamber.
11. The flow control device of claim 10 wherein the annular fluid chamber is filled with fluid.
12. The flow control device of claim 11 wherein the fluid comprises nitrogen.
13. The flow control device of claim 11 wherein the fluid comprises water.
14. The flow control device of claim 11 wherein the fluid comprises silicon type oil.
15. A flow control device for selectively closing a tubing string to fluid flow therethrough, the device comprising: a housing defining a flowbore therethrough; a radially inwardly projecting shell retained within the flowbore to provide a flowbore portion having restricted diameter, the shell further presenting a plug member seat; and the shell being deformable to permit a plug member to pass through the restricted diameter upon application of a predetermined amount of force to the plug member.
16. The flow control device of claim 15 wherein the shell is elastically deformable.
17. The flow control device of claim 15 wherein the shell is plastically deformable.
18. The flow control device of claim 15 further comprising a plug member shaped and sized to fit within the flowbore and be seated upon the plug member seat.
19. The flow control device of claim 15 wherein the shell defines an annular fluid chamber that is filled with fluid.
20. The flow control device of claim 15 wherein the shell is substantially formed of a metal alloy.
21. The flow control device of claim 15 wherein the shell is formed of an elastomeric material.
22. The flow control device of claim 15 wherein the shell is formed of plastic.
23. The flow control device of claim 15 wherein the shell is formed of a composite material.
24. A method of flow control within a production tubing string for temporarily blocking flow through the tubing string, the method comprising the steps of: incorporating a flow control device within a tubing string, the flow control device having a housing defining a flowbore therein, and a restricted throat portion within the flowbore formed by a radially inwardly projecting shell that presents a plug member seat; disposing a plug member within the tubing string to seat the plug member upon the plug member seat; increasing fluid pressure within the tubing string above the plug member to a first level to create a fluid seal, thereby blocking fluid flow within the tubing string; and increasing fluid pressure within the tubing string above the plug member to a second level to force the plug member through the restricted throat portion and unblock the tubing string to fluid flow therethrough.
25. The method of claim 24 further comprising the steps of: disposing a second plug member within the tubing string to seat upon the plug member seat; increasing fluid pressure within the tubing string above the second plug member to said first level to create a fluid seal, thereby blocking fluid flow within the tubing string.
26. The method of claim 25 further comprising the step of increasing fluid pressure within the tubing string above the second plug member to a second level to force the second plug member through the restricted throat portion and unblock the tubing string to fluid flow therethrough.
PCT/US2004/018756 2003-06-24 2004-06-15 Plug and expel flow control device WO2005001240A1 (en)

Priority Applications (2)

Application Number Priority Date Filing Date Title
AU2004252506A AU2004252506B2 (en) 2003-06-24 2004-06-15 Plug and expel flow control device
NO20060107A NO338390B1 (en) 2003-06-24 2006-01-06 Flow control device and flow control method for selectively closing a production flow string for fluid flow therethrough

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
US10/602,578 2003-06-24
US10/602,578 US6966368B2 (en) 2003-06-24 2003-06-24 Plug and expel flow control device

Publications (1)

Publication Number Publication Date
WO2005001240A1 true WO2005001240A1 (en) 2005-01-06

Family

ID=33539578

Family Applications (1)

Application Number Title Priority Date Filing Date
PCT/US2004/018756 WO2005001240A1 (en) 2003-06-24 2004-06-15 Plug and expel flow control device

Country Status (5)

Country Link
US (1) US6966368B2 (en)
AU (1) AU2004252506B2 (en)
NO (1) NO338390B1 (en)
RU (1) RU2352767C2 (en)
WO (1) WO2005001240A1 (en)

Families Citing this family (55)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US10316616B2 (en) 2004-05-28 2019-06-11 Schlumberger Technology Corporation Dissolvable bridge plug
US8211247B2 (en) * 2006-02-09 2012-07-03 Schlumberger Technology Corporation Degradable compositions, apparatus comprising same, and method of use
US7387165B2 (en) 2004-12-14 2008-06-17 Schlumberger Technology Corporation System for completing multiple well intervals
US8567494B2 (en) 2005-08-31 2013-10-29 Schlumberger Technology Corporation Well operating elements comprising a soluble component and methods of use
US8770261B2 (en) 2006-02-09 2014-07-08 Schlumberger Technology Corporation Methods of manufacturing degradable alloys and products made from degradable alloys
US7513311B2 (en) * 2006-04-28 2009-04-07 Weatherford/Lamb, Inc. Temporary well zone isolation
US20080110643A1 (en) * 2006-11-09 2008-05-15 Baker Hughes Incorporated Large bore packer and methods of setting same
US8069922B2 (en) * 2008-10-07 2011-12-06 Schlumberger Technology Corporation Multiple activation-device launcher for a cementing head
GB0912030D0 (en) * 2009-07-10 2009-08-19 Simonian Sam Flow restrictor device
US8347965B2 (en) * 2009-11-10 2013-01-08 Sanjel Corporation Apparatus and method for creating pressure pulses in a wellbore
WO2011146866A2 (en) 2010-05-21 2011-11-24 Schlumberger Canada Limited Method and apparatus for deploying and using self-locating downhole devices
US8813849B1 (en) 2010-06-21 2014-08-26 Raymond C. Davis Oil well safety valve apparatus and method
US8991505B2 (en) * 2010-10-06 2015-03-31 Colorado School Of Mines Downhole tools and methods for selectively accessing a tubular annulus of a wellbore
US9562419B2 (en) 2010-10-06 2017-02-07 Colorado School Of Mines Downhole tools and methods for selectively accessing a tubular annulus of a wellbore
US9382790B2 (en) 2010-12-29 2016-07-05 Schlumberger Technology Corporation Method and apparatus for completing a multi-stage well
US8668018B2 (en) 2011-03-10 2014-03-11 Baker Hughes Incorporated Selective dart system for actuating downhole tools and methods of using same
US8668006B2 (en) 2011-04-13 2014-03-11 Baker Hughes Incorporated Ball seat having ball support member
US8479808B2 (en) 2011-06-01 2013-07-09 Baker Hughes Incorporated Downhole tools having radially expandable seat member
US9145758B2 (en) 2011-06-09 2015-09-29 Baker Hughes Incorporated Sleeved ball seat
US8944171B2 (en) 2011-06-29 2015-02-03 Schlumberger Technology Corporation Method and apparatus for completing a multi-stage well
US9033041B2 (en) 2011-09-13 2015-05-19 Schlumberger Technology Corporation Completing a multi-stage well
US10364629B2 (en) 2011-09-13 2019-07-30 Schlumberger Technology Corporation Downhole component having dissolvable components
US9752407B2 (en) 2011-09-13 2017-09-05 Schlumberger Technology Corporation Expandable downhole seat assembly
US9534471B2 (en) 2011-09-30 2017-01-03 Schlumberger Technology Corporation Multizone treatment system
CN103917738A (en) 2011-10-11 2014-07-09 帕克斯普拉斯能源服务有限公司 Wellbore actuators, treatment strings and methods
US9394752B2 (en) 2011-11-08 2016-07-19 Schlumberger Technology Corporation Completion method for stimulation of multiple intervals
US9238953B2 (en) 2011-11-08 2016-01-19 Schlumberger Technology Corporation Completion method for stimulation of multiple intervals
US9004091B2 (en) 2011-12-08 2015-04-14 Baker Hughes Incorporated Shape-memory apparatuses for restricting fluid flow through a conduit and methods of using same
AU2012351995A1 (en) 2011-12-14 2014-06-26 Utex Industries, Inc. Expandable seat assembly for isolating fracture zones in a well
US9279306B2 (en) 2012-01-11 2016-03-08 Schlumberger Technology Corporation Performing multi-stage well operations
US8844637B2 (en) 2012-01-11 2014-09-30 Schlumberger Technology Corporation Treatment system for multiple zones
US9016388B2 (en) * 2012-02-03 2015-04-28 Baker Hughes Incorporated Wiper plug elements and methods of stimulating a wellbore environment
US9353598B2 (en) 2012-05-09 2016-05-31 Utex Industries, Inc. Seat assembly with counter for isolating fracture zones in a well
US20130327519A1 (en) * 2012-06-07 2013-12-12 Schlumberger Technology Corporation Tubing test system
US9074437B2 (en) * 2012-06-07 2015-07-07 Baker Hughes Incorporated Actuation and release tool for subterranean tools
US9650851B2 (en) 2012-06-18 2017-05-16 Schlumberger Technology Corporation Autonomous untethered well object
US9556704B2 (en) 2012-09-06 2017-01-31 Utex Industries, Inc. Expandable fracture plug seat apparatus
US9988867B2 (en) 2013-02-01 2018-06-05 Schlumberger Technology Corporation Deploying an expandable downhole seat assembly
US9187978B2 (en) 2013-03-11 2015-11-17 Weatherford Technology Holdings, Llc Expandable ball seat for hydraulically actuating tools
US9631468B2 (en) 2013-09-03 2017-04-25 Schlumberger Technology Corporation Well treatment
US9587477B2 (en) 2013-09-03 2017-03-07 Schlumberger Technology Corporation Well treatment with untethered and/or autonomous device
US10487625B2 (en) 2013-09-18 2019-11-26 Schlumberger Technology Corporation Segmented ring assembly
US9644452B2 (en) 2013-10-10 2017-05-09 Schlumberger Technology Corporation Segmented seat assembly
US9523258B2 (en) 2013-11-18 2016-12-20 Weatherford Technology Holdings, Llc Telemetry operated cementing plug release system
US9777569B2 (en) 2013-11-18 2017-10-03 Weatherford Technology Holdings, Llc Running tool
US9528346B2 (en) 2013-11-18 2016-12-27 Weatherford Technology Holdings, Llc Telemetry operated ball release system
US9428998B2 (en) 2013-11-18 2016-08-30 Weatherford Technology Holdings, Llc Telemetry operated setting tool
GB2544002B (en) * 2014-07-28 2019-04-10 Baker Hughes Inc Downhole system using packer setting joint and method
US10337288B2 (en) 2015-06-10 2019-07-02 Weatherford Technology Holdings, Llc Sliding sleeve having indexing mechanism and expandable sleeve
US10711560B2 (en) 2015-07-09 2020-07-14 Halliburton Energy Services, Inc. Wellbore plug sealing assembly
US10538988B2 (en) 2016-05-31 2020-01-21 Schlumberger Technology Corporation Expandable downhole seat assembly
MY197716A (en) * 2018-09-17 2023-07-10 Halliburton Energy Services Inc Two part bonded seal for static downhole tool applications
US10961815B2 (en) 2019-08-13 2021-03-30 Weatherford Technology Holdings, Llc Apparatus and method for wet shoe applications
US11867019B2 (en) 2022-02-24 2024-01-09 Weatherford Technology Holdings, Llc Apparatus and method for pressure testing in wet shoe applications
US20240026751A1 (en) * 2022-07-21 2024-01-25 Halliburton Energy Services, Inc. Tapered collet mechanism for shifting plug release

Citations (3)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US4566541A (en) * 1983-10-19 1986-01-28 Compagnie Francaise Des Petroles Production tubes for use in the completion of an oil well
US4606408A (en) * 1985-02-20 1986-08-19 Halliburton Company Method and apparatus for gravel-packing a well
US20010045288A1 (en) * 2000-02-04 2001-11-29 Allamon Jerry P. Drop ball sub and system of use

Family Cites Families (16)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US2829719A (en) * 1954-04-02 1958-04-08 Baker Oil Tools Inc Variable orifice casing filling apparatus
US3054415A (en) * 1959-08-03 1962-09-18 Baker Oil Tools Inc Sleeve valve apparatus
US4474241A (en) * 1983-02-14 1984-10-02 Halliburton Company Differential fill valve assembly
US4828037A (en) * 1988-05-09 1989-05-09 Lindsey Completion Systems, Inc. Liner hanger with retrievable ball valve seat
US4893678A (en) * 1988-06-08 1990-01-16 Tam International Multiple-set downhole tool and method
US4823882A (en) * 1988-06-08 1989-04-25 Tam International, Inc. Multiple-set packer and method
US5146992A (en) * 1991-08-08 1992-09-15 Baker Hughes Incorporated Pump-through pressure seat for use in a wellbore
US5244044A (en) * 1992-06-08 1993-09-14 Otis Engineering Corporation Catcher sub
US5413172A (en) * 1992-11-16 1995-05-09 Halliburton Company Sub-surface release plug assembly with non-metallic components
WO1995017347A1 (en) * 1993-12-23 1995-06-29 Ppg Industries, Inc. Silica aerogel produced under subcritical conditions
US5695009A (en) * 1995-10-31 1997-12-09 Sonoma Corporation Downhole oil well tool running and pulling with hydraulic release using deformable ball valving member
US5845711A (en) * 1995-06-02 1998-12-08 Halliburton Company Coiled tubing apparatus
GB9702266D0 (en) * 1997-02-04 1997-03-26 Specialised Petroleum Serv Ltd A valve device
US5890538A (en) * 1997-04-14 1999-04-06 Amoco Corporation Reverse circulation float equipment tool and process
US5996696A (en) * 1997-06-27 1999-12-07 Fike Corporation Method and apparatus for testing the integrity of oil delivery tubing within an oil well casing
US20020162261A1 (en) 2001-04-23 2002-11-07 West Henry L. Medication identification system

Patent Citations (3)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US4566541A (en) * 1983-10-19 1986-01-28 Compagnie Francaise Des Petroles Production tubes for use in the completion of an oil well
US4606408A (en) * 1985-02-20 1986-08-19 Halliburton Company Method and apparatus for gravel-packing a well
US20010045288A1 (en) * 2000-02-04 2001-11-29 Allamon Jerry P. Drop ball sub and system of use

Also Published As

Publication number Publication date
US20040262016A1 (en) 2004-12-30
AU2004252506B2 (en) 2009-06-11
NO338390B1 (en) 2016-08-15
RU2352767C2 (en) 2009-04-20
AU2004252506A1 (en) 2005-01-06
RU2006101721A (en) 2007-07-27
NO20060107L (en) 2006-01-23
US6966368B2 (en) 2005-11-22

Similar Documents

Publication Publication Date Title
US6966368B2 (en) Plug and expel flow control device
EP1693547B1 (en) Method and apparatus for well testing
EP0261287B1 (en) Fluid pressure actuated downhole apparatus
EP0846839B1 (en) Method and apparatus for placing and cementing casing in horizontal wells
US3779263A (en) Pressure responsive auxiliary disc valve and the like for well cleaning, testing, and other operations
CA3017961C (en) Toe valve
US5615741A (en) Packer inflation system
US20080164029A1 (en) Apparatus and method for forming multiple plugs in a wellbore
CA3039472C (en) Top plug with transitionable seal
US20050103493A1 (en) Moled foam plugs, plug systems and methods of using same
WO2006119129A2 (en) High pressure expandable packer
WO2018080928A1 (en) Casing floatation system with latch-in plugs
NO318948B1 (en) Inflatable gasket
EP2436874A1 (en) Drill pipe
EP0952303A2 (en) Apparatus positionable in a subterranean well, comprising releasably secured members
US20110186304A1 (en) T-Frac Zone Test Tool and System
RU2146326C1 (en) Device for closing of pipes below immersible pump
CA2724499A1 (en) T-frac zone test tool and system

Legal Events

Date Code Title Description
AK Designated states

Kind code of ref document: A1

Designated state(s): AE AG AL AM AT AU AZ BA BB BG BR BW BY BZ CA CH CN CO CR CU CZ DE DK DM DZ EC EE EG ES FI GB GD GE GH GM HR HU ID IL IN IS JP KE KG KP KR KZ LC LK LR LS LT LU LV MA MD MG MK MN MW MX MZ NA NI NO NZ OM PG PH PL PT RO RU SC SD SE SG SK SL SY TJ TM TN TR TT TZ UA UG UZ VC VN YU ZA ZM ZW

AL Designated countries for regional patents

Kind code of ref document: A1

Designated state(s): BW GH GM KE LS MW MZ NA SD SL SZ TZ UG ZM ZW AM AZ BY KG KZ MD RU TJ TM AT BE BG CH CY CZ DE DK EE ES FI FR GB GR HU IE IT LU MC NL PL PT RO SE SI SK TR BF BJ CF CG CI CM GA GN GQ GW ML MR NE SN TD TG

121 Ep: the epo has been informed by wipo that ep was designated in this application
DPEN Request for preliminary examination filed prior to expiration of 19th month from priority date (pct application filed from 20040101)
WWE Wipo information: entry into national phase

Ref document number: 2004252506

Country of ref document: AU

ENP Entry into the national phase

Ref document number: 2004252506

Country of ref document: AU

Date of ref document: 20040615

Kind code of ref document: A

WWP Wipo information: published in national office

Ref document number: 2004252506

Country of ref document: AU

WWE Wipo information: entry into national phase

Ref document number: 2006101721

Country of ref document: RU

122 Ep: pct application non-entry in european phase