US20210010347A1 - Choke system for a downhole valve - Google Patents
Choke system for a downhole valve Download PDFInfo
- Publication number
- US20210010347A1 US20210010347A1 US16/505,802 US201916505802A US2021010347A1 US 20210010347 A1 US20210010347 A1 US 20210010347A1 US 201916505802 A US201916505802 A US 201916505802A US 2021010347 A1 US2021010347 A1 US 2021010347A1
- Authority
- US
- United States
- Prior art keywords
- choke
- tubular
- actuator
- elements
- selectively
- 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.)
- Granted
Links
Images
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
- E21B34/00—Valve arrangements for boreholes or wells
- E21B34/06—Valve arrangements for boreholes or wells in wells
- E21B34/10—Valve arrangements for boreholes or wells in wells operated by control fluid supplied from outside the borehole
-
- E21B2034/007—
-
- 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
- E21B2200/00—Special features related to earth drilling for obtaining oil, gas or water
- E21B2200/06—Sleeve valves
Abstract
A choke system for a downhole valve including a first tubular having an outer surface, an inner surface, and a first flow port extending through the outer surface and the inner surface. A second tubular is shiftably arranged relative to the first tubular radially inwardly of the inner surface. The second tubular includes a second flow port that is selectively aligned with the first flow port. A choke member including a choke opening is positioned between the first tubular and the second tubular. The choke member is selectively shiftable and rotatable relative to the first tubular and the second tubular. A choke actuator is axially aligned with the choke member and positioned between the first tubular and the second tubular. The choke actuator being selectively shiftable to unseat the choke member and rotate the choke opening relative to the first and second flow ports.
Description
- In the resource recovery industry valves are employed to control flow from, for example, an annulus, into a flow path of a tubular. The valve may allow formation fluids to flow to a surface system for collection, testing, and/or processing. In some installations, a choke or flow restrictor may be employed in connection with the valve. The choke extends about and is fixed relative to the valve. The choke includes a selected opening geometry that exposes different portions of the valve depending on valve position.
- The valve may be opened or closed by applying pressure to one or more actuators, Each time the valve is shifted from an open to closed position, a rotation occurs relative to the choke. Thus, setting the desired choke requires multiple open and close operations of the valve. Each open and close operation of the valve places stress on valve seals, requires a long actuation stroke, e.g., entire valve opening must shift relative to a valve inlet and the choke. Further, any adjustment of the choke requires the valve to cycle between open and closed positions. Accordingly, the industry would welcome a choke system that allows for setting a choke position independent of the valve.
- Disclosed is a choke system for a downhole valve including a first tubular having an outer surface, an inner surface, and a first flow port extending through the outer surface and the inner surface. A second tubular is shiftably arranged relative to the first tubular radially inwardly of the inner surface. The second tubular includes a second flow port that is selectively aligned with the first flow port. A choke member including a choke opening is positioned between the first tubular and the second tubular. The choke member is selectively shiftable and rotatable relative to the first tubular and the second tubular. A choke actuator is axially aligned with the choke member and positioned between the first tubular and the second tubular. The choke actuator being selectively shiftable to unseat the choke member and rotate the choke opening relative to the first and second flow ports.
- The following descriptions should not be considered limiting in any way. With reference to the accompanying drawings, like elements are numbered alike:
-
FIG. 1 depicts a resource exploration and recovery system including a valve having a choke system, in accordance with an exemplary embodiment; -
FIG. 2 depicts a cross-sectional view of the valve and choke system ofFIG. 1 , in accordance with an aspect of an exemplary embodiment -
FIG. 3A depicts a choke member and choke actuator of the valve and choke system ofFIG. 2 , in accordance with an aspect of an exemplary embodiment; -
FIG. 3B depicts an interface between the choke member and choke actuator ofFIG. 3A , in accordance with an aspect of an exemplary embodiment; -
FIG. 4 depicts a cross-sectional view of a valve and choke system, in accordance with another aspect of an exemplary embodiment; -
FIG. 5 depicts a choke member and choke actuator of the valve and choke system ofFIG. 4 , in accordance with another aspect of an exemplary embodiment; -
FIG. 6 depicts a choke member and choke actuator of the valve and choke system ofFIG. 4 , in accordance with yet another aspect of an exemplary embodiment; - A detailed description of one or more embodiments of the disclosed apparatus and method are presented herein by way of exemplification and not limitation with reference to the Figures.
- A resource exploration and recovery system, in accordance with an exemplary embodiment, is indicated generally at 10, in
FIGS. 1 and 2 . Resource exploration and recovery system 10 should be understood to include well drilling operations, completions, resource extraction and recovery, CO2 sequestration, and the like. Resource exploration and recovery system 10 may include afirst system 14 which, in some environments, may take the form of asurface system 16 operatively and fluidically connected to asecond system 18 which, in some environments, may take the form of a downhole system. -
First system 14 may include acontrol system 23 that may provide power to, monitor, communicate with, and/or activate one or more downhole operations as will be discussed herein.Surface system 16 may include additional systems such as pumps, fluid storage systems, cranes and the like (not shown).Second system 18 may include atubular string 30 that extends into awellbore 34 formed in formation 36.Tubular string 30 may take the form of a plurality of interconnected tubulars, coil tubing, or the like. Wellbore 34 includes anannular wall 38 which may be defined by a surface of formation 36. Further, it should be understood, thatwellbore 34 may include a casing tubular (not shown).Tubular string 30 may support avalve 45 including one or morefirst flow ports 48. - Referring to
FIGS. 2 and 3A ,valve 45 includes a first tubular 54 and a second tubular 56 arranged within first tubular 54. First tubular 54 includes anouter surface 60 and aninner surface 62. A plurality ofchoke support elements 66 projects radially inwardly frominner surface 62.Second tubular 56 includes anouter surface portion 70 and aninner surface portion 72 that defines aflow path 74. A plurality of second flow ports, one of which is indicated at 78, is formed in second tubular 56. Second tubular 56 is axially shiftable within first tubular 54 such thatsecond flow ports 78 may selectively align withfirst flow ports 48. - In an embodiment,
valve 45 includes achoke member 84 that is selectively positioned to establish a selected size ofsecond flow ports 78. In an embodiment,choke member 84 includes a firstaxial end 86, a secondaxial end 87, and anintermediate portion 89 extending therebetween.Intermediate portion 89 includes a plurality of choke openings, one of which is indicated at 92, having a shape that is configured to selectively establish a size ofsecond flow ports 78. Firstaxial end 86 includes a plurality oftooth elements 94 that cooperate with achoke actuator 96 to rotatechoke member 84. That is, as will be discussed herein,choke member 84 is selectively rotated so thatchoke opening 92 exposes more or less ofsecond flow ports 78 to achieve a desired flow rate betweenflow ports 48 andflow path 74. - In an embodiment,
choke actuator 96 includes afirst end 98 and asecond end 99. A plurality ofactuator elements 102 project axially outwardly offirst end 98. Anannular seal 105 may be arranged axially outwardly ofsecond end 99. As shown inFIG. 3B , each of the plurality ofactuator elements 102 extends between adjacent ones of the plurality ofchoke support elements 66 and includes aterminal end portion 108 having anangled surface portion 110. Each of the plurality ofchoke support elements 66 includes aterminal end section 115 having anangled surface section 117. Eachangled surface portion 110 andangled surface section 117 align to form achoke support surface 120. Further, eachangled surface portion 110 andangled surface section 117 includes an angle that is complimentary of an angle defined bytooth elements 94. - In an embodiment, pressure may be applied to choke
actuator 96 viaannular seal 105. The pressure causeschoke actuator 96 to shift axially such that actuation elements act upontooth elements 94unseating choke member 84 from choke support elements 113.Actuation elements 102force choke member 84 againstspring 124. An interaction betweenangled surface portions 110 andtooth elements 94 causes chokemember 84 to rotate and change a degree of opening ofsecond flow port 78. Pressure may be relieved allowingspring 124 to urgechoke member 84 back onto choke support elements 113. Each application of pressure unseats and rotateschoke member 84 by onetooth element 94 so as to further change the degree of opening ofsecond flow port 78. - Referring to
FIGS. 4 and 5 wherein like reference numbers represent corresponding parts in the respective views, in describing first tubular 140 in accordance with another aspect of an exemplary embodiment. First tubular 140 includes anouter surface 142 and aninner surface 144. Achoke support 146 is formed ininner surface 144.Choke support 146 includes a plurality of choke support elements, one of which is indicated at 148 each having anangled surface section 150. In addition, a plurality of guide elements, one of which is shown at 151 project radially inwardly ofinner surface 144. - A
choke actuator 154 is arranged radially inwardly ofinner surface 144 and substantially axially aligned withchoke member 84.Choke actuator 154 includes afirst end 157 and asecond end 158.Annular seal 105 is arranged axially outwardly ofsecond end 158. A plurality ofactuator elements 160 extend axially outwardly offirst end 157. Each of the plurality ofactuator elements 160 includes aterminal end portion 166 having anangled surface portion 168.Angled surface portion 168 may include one or more angled surfaces. In an embodiment, each of the plurality ofguide elements 151 are arranged between corresponding ones of the plurality ofactuator elements 160.Guide elements 151 prevent rotation ofchoke actuator 154. - In an embodiment, pressure may be applied to choke
actuator 154 viaannular seal 105. The pressure causeschoke actuator 154 to shift axially such that actuation elements act upontooth elements 94 unseatingchoke member 84 fromchoke support elements 148.Actuation elements 160force choke member 84 againstspring 124. An interaction betweenangled surface portions 168 andtooth elements 94 causes chokemember 84 to rotate and change a degree of opening ofsecond flow port 78. Pressure may be relieved allowingspring 124 to urgechoke member 154 back ontochoke support elements 148 ofchoke support 146. Each application of pressure unseats and rotateschoke member 84 by onetooth element 94 so as to further change the degree of opening ofsecond flow ports 78. - Reference will now follow to
FIG. 6 , wherein like reference numbers represent corresponding parts in the respective views, in describing achoke actuator 180 in accordance with yet another aspect of an exemplary embodiment.Choke actuator 180 includes afirst end 182 and asecond end 183.Annular seal 105 is arranged axially outwardly ofsecond end 183. A plurality ofactuator elements 185 extend axially outwardly offirst end 182. Each of the plurality ofactuator elements 185 includes aterminal end portion 191 having anangled surface portion 193. In an embodiment, each of the plurality ofactuator elements 185 is flexible. That is, each of the plurality ofactuator elements 185 may deflect circumferentially when urged into contact withchoke member 84 to adjust a degree of opening ofsecond flow ports 78. - At this point, it should be understood that the exemplary embodiments describe a valve including an independent choke. That is, the choke is decoupled from the opening and closing of the valve. In this manner, an overall axial length of the valve may be reduced. Further, the valve may be operated regardless of a position of the choke. That is, instead of opening and closing a valve to set the choke, a number of pressure applications may be applied to the choke system to set the selected degree of opening. Once the selected degree of opening is established the valve may be opened. In this manner, flow may pass uninterrupted between formation 36 and flow
path 74. - Embodiment 1. A choke system for a downhole valve comprising: a first tubular including an outer surface, an inner surface, and a first flow port extending through the outer surface and the inner surface; a second tubular shiftably arranged relative to the first tubular radially inwardly of the inner surface, the second tubular including a second flow port that is selectively aligned with the first flow port; a choke member including a choke opening positioned between the first tubular and the second tubular, the choke member being selectively shiftable and rotatable relative to the first tubular and the second tubular; and a choke actuator axially aligned with the choke member and positioned between the first tubular and the second tubular, the choke actuator being selectively shiftable to unseat the choke member and rotate the choke opening relative to the first and second flow ports.
- Embodiment 2. The choke system according to any prior embodiment, further comprising: a return spring positioned to bias the choke member toward the choke actuator.
- Embodiment 3. The choke system according to any prior embodiment, wherein the return spring extends about the second tubular.
- Embodiment 4. The choke system according to any prior embodiment, wherein the choke actuator includes a first end, a second end, and a plurality of actuator elements extending axially outwardly of the first end.
- Embodiment 5. The choke system according to any prior embodiment, further comprising: a plurality of choke support elements provided at the inner surface of the first tubular.
- Embodiment 6. The choke system according to any prior embodiment, wherein each of the plurality of actuator elements extend between adjacent ones of the plurality of choke support elements.
- Embodiment 7. The choke system according to any prior embodiment, wherein each of the plurality of actuator elements includes a terminal end portion including an angled surface portion and each of the plurality of choke support elements includes a terminal end section including an angled surface section.
- Embodiment 8. The choke system according to any prior embodiment, wherein the angled surface portion of each of the plurality of actuator elements selectively aligns with corresponding ones of the angled surface section of each of the plurality of choke support elements to form a choke support surface.
- Embodiment 9. The choke system according to any prior embodiment, wherein the choke member includes a first axial end and an opposing second axial end, the opposing second axial end including a plurality of tooth elements that selectively engage with the choke support surface.
- Embodiment 10. The choke system according to any prior embodiment, wherein the plurality of actuator elements are arranged radially inwardly of the plurality of choke support elements.
- Embodiment 11. The choke system according to any prior embodiment, further comprising: a plurality of guide elements extending radially inwardly of the first tubular, each of the plurality of guide elements extending between adjacent ones of the plurality of actuation elements.
- Embodiment 12. The choke system according to any prior embodiment, wherein each of the plurality of actuator elements includes a terminal end portion including an angled surface portion having one or more angled surfaces.
- Embodiment 13. The choke system according to any prior embodiment, wherein each of the plurality of actuator elements is circumferentially deformable.
-
Embodiment 14. The choke system according to any prior embodiment, wherein each of the plurality of actuator elements includes a terminal end portion including an angled end portion. - The use of the terms “a” and “an” and “the” and similar referents in the context of describing the invention (especially in the context of the following claims) are to be construed to cover both the singular and the plural, unless otherwise indicated herein or clearly contradicted by context. Further, it should be noted that the terms “first,” “second,” and the like herein do not denote any order, quantity, or importance, but rather are used to distinguish one element from another.
- The terms “about” and “substantially” are intended to include the degree of error associated with measurement of the particular quantity based upon the equipment available at the time of filing the application. For example, “about” and/or “substantially” can include a range of ±8% or 5%, or 2% of a given value.
- The teachings of the present disclosure may be used in a variety of well operations. These operations may involve using one or more treatment agents to treat a formation, the fluids resident in a formation, a wellbore, and/or equipment in the wellbore, such as production tubing. The treatment agents may be in the form of liquids, gases, solids, semi-solids, and mixtures thereof. Illustrative treatment agents include, but are not limited to, fracturing fluids, acids, steam, water, brine, anti-corrosion agents, cement, permeability modifiers, drilling muds, emulsifiers, demulsifiers, tracers, flow improvers etc. Illustrative well operations include, but are not limited to, hydraulic fracturing, stimulation, tracer injection, cleaning, acidizing, steam injection, water flooding, cementing, etc.
- While the invention has been described with reference to an exemplary embodiment or embodiments, it will be understood by those skilled in the art that various changes may be made and equivalents may be substituted for elements thereof without departing from the scope of the invention. In addition, many modifications may be made to adapt a particular situation or material to the teachings of the invention without departing from the essential scope thereof. Therefore, it is intended that the invention not be limited to the particular embodiment disclosed as the best mode contemplated for carrying out this invention, but that the invention will include all embodiments falling within the scope of the claims. Also, in the drawings and the description, there have been disclosed exemplary embodiments of the invention and, although specific terms may have been employed, they are unless otherwise stated used in a generic and descriptive sense only and not for purposes of limitation, the scope of the invention therefore not being so limited.
Claims (14)
1. A choke system for a downhole valve comprising:
a first tubular including an outer surface, an inner surface, and a first flow port extending through the outer surface and the inner surface;
a second tubular shiftably arranged relative to the first tubular radially inwardly of the inner surface, the second tubular including a second flow port that is selectively aligned with the first flow port;
a choke member including a choke opening positioned between the first tubular and the second tubular, the choke member being selectively shiftable and rotatable relative to the first tubular and the second tubular;
a choke actuator axially aligned with the choke member and positioned between the first tubular and the second tubular, the choke actuator being selectively shiftable to unseat the choke member and rotate the choke opening relative to the first and second flow ports; and
a return spring positioned to bias the choke member toward the choke actuator.
2. (canceled)
3. The choke system according to claim 1 , wherein the return spring extends about the second tubular.
4. A choke system for a downhole valve comprising:
a first tubular including an outer surface, an inner surface, and a first flow port extending through the outer surface and the inner surface;
a second tubular shiftably arranged relative to the first tubular radially inwardly of the inner surface, the second tubular including a second flow port that is selectively aligned with the first flow port;
a choke member including a choke opening positioned between the first tubular and the second tubular, the choke member being selectively shiftable and rotatable relative to the first tubular and the second tubular;
a plurality of choke support elements provided at the inner surface of the first tubular; and
a choke actuator axially aligned with the choke member and positioned between the first tubular and the second tubular, the choke actuator being selectively shiftable to unseat the choke member and rotate the choke opening relative to the first and second flow ports, wherein the choke actuator includes a first end, a second end, and a plurality of actuator elements extending axially outwardly of the first end.
5. (canceled)
6. The choke system according to claim 4 , wherein each of the plurality of actuator elements extend between adjacent ones of the plurality of choke support elements.
7. The choke system according to claim 6 , wherein each of the plurality of actuator elements includes a terminal end portion including an angled surface portion and each of the plurality of choke support elements includes a terminal end section including an angled surface section.
8. The choke system according to claim 7 , wherein the angled surface portion of each of the plurality of actuator elements selectively aligns with corresponding ones of the angled surface section of each of the plurality of choke support elements to form a choke support surface.
9. The choke system according to claim 8 , wherein the choke member includes a first axial end and an opposing second axial end, the opposing second axial end including a plurality of tooth elements that selectively engage with the choke support surface.
10. The choke system according to claim 4 , wherein the plurality of actuator elements are arranged radially inwardly of the plurality of choke support elements.
11. The choke system according to claim 10 , further comprising: a plurality of guide elements extending radially inwardly of the first tubular, each of the plurality of guide elements extending between adjacent ones of the plurality of actuator elements.
12. The choke system according to claim 10 , wherein each of the plurality of actuator elements includes a terminal end portion including an angled surface portion having one or more angled surfaces.
13. The choke system according to claim 10 , wherein each of the plurality of actuator elements is circumferentially deformable.
14. The choke system according to claim 13 , wherein each of the plurality of actuator elements includes a terminal end portion including an angled end portion.
Priority Applications (6)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
US16/505,802 US10907444B1 (en) | 2019-07-09 | 2019-07-09 | Choke system for a downhole valve |
BR112022000090A BR112022000090A2 (en) | 2019-07-09 | 2020-06-29 | Throttle system for a downhole valve |
AU2020309495A AU2020309495B2 (en) | 2019-07-09 | 2020-06-29 | Choke system for a downhole valve |
CN202080049586.4A CN114080487B (en) | 2019-07-09 | 2020-06-29 | Choke system for downhole valve |
PCT/US2020/040095 WO2021007059A1 (en) | 2019-07-09 | 2020-06-29 | Choke system for a downhole valve |
NO20220038A NO20220038A1 (en) | 2019-07-09 | 2022-01-11 | Choke system for a downhole valve |
Applications Claiming Priority (1)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
US16/505,802 US10907444B1 (en) | 2019-07-09 | 2019-07-09 | Choke system for a downhole valve |
Publications (2)
Publication Number | Publication Date |
---|---|
US20210010347A1 true US20210010347A1 (en) | 2021-01-14 |
US10907444B1 US10907444B1 (en) | 2021-02-02 |
Family
ID=74102594
Family Applications (1)
Application Number | Title | Priority Date | Filing Date |
---|---|---|---|
US16/505,802 Active US10907444B1 (en) | 2019-07-09 | 2019-07-09 | Choke system for a downhole valve |
Country Status (6)
Country | Link |
---|---|
US (1) | US10907444B1 (en) |
CN (1) | CN114080487B (en) |
AU (1) | AU2020309495B2 (en) |
BR (1) | BR112022000090A2 (en) |
NO (1) | NO20220038A1 (en) |
WO (1) | WO2021007059A1 (en) |
Families Citing this family (1)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
EP3810889A4 (en) | 2018-06-22 | 2022-04-06 | Services Pétroliers Schlumberger | Full bore electric flow control valve system |
Family Cites Families (14)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
AU755555B2 (en) * | 1997-07-21 | 2002-12-12 | Halliburton Energy Services, Inc. | Flow control apparatus for use in a subterranean well and associated methods |
US5957208A (en) | 1997-07-21 | 1999-09-28 | Halliburton Energy Services, Inc. | Flow control apparatus |
DK1064451T3 (en) * | 1998-03-14 | 2003-03-03 | Andrew Philip Churchill | Pressure-activated borehole tool |
US6371208B1 (en) * | 1999-06-24 | 2002-04-16 | Baker Hughes Incorporated | Variable downhole choke |
US6644412B2 (en) * | 2001-04-25 | 2003-11-11 | Weatherford/Lamb, Inc. | Flow control apparatus for use in a wellbore |
US6948561B2 (en) | 2002-07-12 | 2005-09-27 | Baker Hughes Incorporated | Indexing apparatus |
GB0509800D0 (en) | 2005-05-13 | 2005-06-22 | Petrowell Ltd | Apparatus |
US9328579B2 (en) * | 2012-07-13 | 2016-05-03 | Weatherford Technology Holdings, Llc | Multi-cycle circulating tool |
US9500063B2 (en) * | 2013-08-09 | 2016-11-22 | Tam International, Inc. | Hydraulic cycle opening sleeve |
US9670750B2 (en) * | 2013-08-09 | 2017-06-06 | Team Oil Tools, Lp | Methods of operating well bore stimulation valves |
US10030478B2 (en) | 2014-05-20 | 2018-07-24 | Baker Hughes, A Ge Company, Llc | Mechanically actuated variable choke system for subterranean use |
US10156124B2 (en) * | 2015-01-20 | 2018-12-18 | Tam International, Inc. | Balanced piston toe sleeve |
US10184318B2 (en) * | 2015-08-05 | 2019-01-22 | Colt Petroleum Technology, Llc | Downhole communication valve and method of use |
US10428609B2 (en) * | 2016-06-24 | 2019-10-01 | Baker Hughes, A Ge Company, Llc | Downhole tool actuation system having indexing mechanism and method |
-
2019
- 2019-07-09 US US16/505,802 patent/US10907444B1/en active Active
-
2020
- 2020-06-29 BR BR112022000090A patent/BR112022000090A2/en unknown
- 2020-06-29 WO PCT/US2020/040095 patent/WO2021007059A1/en active Application Filing
- 2020-06-29 AU AU2020309495A patent/AU2020309495B2/en active Active
- 2020-06-29 CN CN202080049586.4A patent/CN114080487B/en active Active
-
2022
- 2022-01-11 NO NO20220038A patent/NO20220038A1/en unknown
Also Published As
Publication number | Publication date |
---|---|
CN114080487B (en) | 2024-04-16 |
AU2020309495A1 (en) | 2022-02-03 |
WO2021007059A1 (en) | 2021-01-14 |
CN114080487A (en) | 2022-02-22 |
AU2020309495B2 (en) | 2023-08-10 |
NO20220038A1 (en) | 2022-01-11 |
BR112022000090A2 (en) | 2022-02-15 |
US10907444B1 (en) | 2021-02-02 |
Similar Documents
Publication | Publication Date | Title |
---|---|---|
US10253623B2 (en) | Diamond high temperature shear valve designed to be used in extreme thermal environments | |
AU2019261880B2 (en) | Downhole component including a unitary body having an internal annular chamber and fluid passages | |
AU2020309495B2 (en) | Choke system for a downhole valve | |
AU2021267826B2 (en) | Indexing valve system for a resource exploration and recovery system | |
US10677018B2 (en) | Actuator mechanism for a valve system | |
US10794143B2 (en) | Sub-surface safety valve flapper sleeve | |
US11753904B2 (en) | Valve having a modular activation system | |
US10794146B2 (en) | Downhole valve assembly having an integrated j-slot | |
US20240141751A1 (en) | Downhole tool including a valve having a modular activation system | |
US11549333B2 (en) | Indexing tool system for a resource exploration and recovery system | |
US11111760B2 (en) | Vectored annular wellbore cleaning system | |
AU2019309219B2 (en) | Fluid injection valve | |
US10781663B2 (en) | Sliding sleeve including a self-holding connection | |
WO2021248163A1 (en) | Tubular for downhole use, a downhole tubular system and method of forming a fluid passageway at a tubular for downhole use |
Legal Events
Date | Code | Title | Description |
---|---|---|---|
AS | Assignment |
Owner name: BAKER HUGHES OILFIELD OPERATIONS LLC, TEXAS Free format text: ASSIGNMENT OF ASSIGNORS INTEREST;ASSIGNOR:BROWN, DONAVAN HOLLAND;REEL/FRAME:049696/0438 Effective date: 20190708 |
|
FEPP | Fee payment procedure |
Free format text: ENTITY STATUS SET TO UNDISCOUNTED (ORIGINAL EVENT CODE: BIG.); ENTITY STATUS OF PATENT OWNER: LARGE ENTITY |
|
STCF | Information on status: patent grant |
Free format text: PATENTED CASE |