US20220049575A1 - Shutoff Valve - Google Patents
Shutoff Valve Download PDFInfo
- Publication number
- US20220049575A1 US20220049575A1 US17/403,705 US202117403705A US2022049575A1 US 20220049575 A1 US20220049575 A1 US 20220049575A1 US 202117403705 A US202117403705 A US 202117403705A US 2022049575 A1 US2022049575 A1 US 2022049575A1
- Authority
- US
- United States
- Prior art keywords
- borehole
- flow tube
- shutoff valve
- valve device
- flapper valve
- 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.)
- Abandoned
Links
- 239000012530 fluid Substances 0.000 claims abstract description 87
- 238000004519 manufacturing process Methods 0.000 claims abstract description 29
- 238000000034 method Methods 0.000 claims description 12
- 239000000463 material Substances 0.000 claims description 7
- 230000006835 compression Effects 0.000 claims description 6
- 238000007906 compression Methods 0.000 claims description 6
- 230000000284 resting effect Effects 0.000 description 11
- 238000007789 sealing Methods 0.000 description 10
- 230000015572 biosynthetic process Effects 0.000 description 8
- 230000008901 benefit Effects 0.000 description 7
- 239000002184 metal Substances 0.000 description 7
- 230000003628 erosive effect Effects 0.000 description 6
- 230000007246 mechanism Effects 0.000 description 6
- 238000006073 displacement reaction Methods 0.000 description 4
- 230000004323 axial length Effects 0.000 description 3
- 238000010008 shearing Methods 0.000 description 3
- VYZAMTAEIAYCRO-UHFFFAOYSA-N Chromium Chemical compound [Cr] VYZAMTAEIAYCRO-UHFFFAOYSA-N 0.000 description 2
- 229910000831 Steel Inorganic materials 0.000 description 2
- 230000004888 barrier function Effects 0.000 description 2
- 230000006837 decompression Effects 0.000 description 2
- 230000005484 gravity Effects 0.000 description 2
- 230000013011 mating Effects 0.000 description 2
- 238000005086 pumping Methods 0.000 description 2
- 230000002441 reversible effect Effects 0.000 description 2
- 239000010959 steel Substances 0.000 description 2
- 241000251468 Actinopterygii Species 0.000 description 1
- 230000004075 alteration Effects 0.000 description 1
- 230000018109 developmental process Effects 0.000 description 1
- 238000005516 engineering process Methods 0.000 description 1
- 238000002347 injection Methods 0.000 description 1
- 239000007924 injection Substances 0.000 description 1
- 230000007257 malfunction Effects 0.000 description 1
- 230000036961 partial effect Effects 0.000 description 1
- 230000003068 static effect Effects 0.000 description 1
- 238000006467 substitution reaction Methods 0.000 description 1
- 230000000007 visual effect Effects 0.000 description 1
- -1 without limitation Substances 0.000 description 1
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
- E21B34/102—Valve arrangements for boreholes or wells in wells operated by control fluid supplied from outside the borehole with means for locking the closing element in open or closed position
- E21B34/103—Valve arrangements for boreholes or wells in wells operated by control fluid supplied from outside the borehole with means for locking the closing element in open or closed position with a shear pin
-
- 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
- E21B34/12—Valve arrangements for boreholes or wells in wells operated by movement of casings or tubings
-
- 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
- E21B34/14—Valve arrangements for boreholes or wells in wells operated by movement of tools, e.g. sleeve valves operated by pistons or wire line tools
-
- 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
- E21B34/08—Valve arrangements for boreholes or wells in wells responsive to flow or pressure of the fluid obtained
- E21B34/085—Valve arrangements for boreholes or wells in wells responsive to flow or pressure of the fluid obtained with time-delay systems, e.g. hydraulic impedance mechanisms
-
- 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
- E21B34/108—Valve arrangements for boreholes or wells in wells operated by control fluid supplied from outside the borehole with time delay systems, e.g. hydraulic impedance mechanisms
-
- 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
- E21B2200/05—Flapper valves
Definitions
- shutoff valve device may comprise a top sub, a bottom sub, and a flow tube
- the bottom sub may comprise a flapper valve and a valve seat
- the flow tube may comprise drag features designed to move the flow tube back and forth from a first position (holding the flapper valve in a completely open position) to a second position (allowing the flapper valve to a closed, sealed position), depending on the direction of fluid flow in the wellbore.
- shutoff valve device for permitting and preventing fluid flow in a production string, comprising: a body comprising a borehole, wherein the body is a top sub coupled to a bottom sub via a threaded fastener; a flow tube disposed within the body's borehole and capable of axial movement within the body's borehole, comprising a flow tube borehole; a bi-directional actuator attached to a bottom opening of the flow tube, comprising flexible flaps; and a flapper valve disposed within the body's borehole, wherein the flapper valve is hingedly coupled to a top surface of the bottom sub and capable of moving between a fully opened and fully closed position.
- a shutoff valve device for permitting and preventing fluid flow in a production string, comprising: a body comprising a borehole, wherein the body is a top sub coupled to a bottom sub via a threaded fastener; a flow tube disposed within the body's borehole and capable of axial movement within the body's borehole, comprising a flow tube borehole; a compression spring disposed radially between the flow tube and the body, wherein the compression spring biases the flow tube in an axially upward position; a bi-directional actuator attached to a bottom opening of the flow tube, comprising flexible flaps; and a flapper valve disposed within the body's borehole, wherein the flapper valve is hingedly coupled to a top surface of the bottom sub and capable of moving between a fully opened and fully closed position.
- One or more specific embodiments disclosed herein includes a method for permitting and preventing fluid flow in a production string, comprising: outfitting a production string with a shutoff valve device comprising: a body comprising a borehole, wherein the body is a top sub coupled to a bottom sub via a threaded fastener; a flow tube disposed within the body's borehole and capable of axial movement within the body's borehole, comprising a flow tube borehole; a bi-directional actuator attached to a bottom opening of the flow tube, comprising flexible flaps; and a flapper valve disposed within the body's borehole, wherein the flapper valve is hingedly coupled to a top surface of the bottom sub and capable of moving between a fully opened and fully closed position.
- FIG. 1A-1C each illustrate a portion of a production string configured with a shutoff valve in accordance with embodiments of the present invention
- FIG. 2 illustrates an internal side view of a shutoff valve in accordance with embodiments of the present invention
- FIG. 3 illustrates a perspective view of a portion of a bottom sub of a shutoff valve in accordance with embodiments of the present invention
- FIGS. 4A-4D each illustrate an orifice disk in accordance with embodiments of the present invention.
- FIGS. 5A and 5B each illustrate an internal side view of an alternative flapper valve in accordance with embodiments of the present invention
- FIG. 6A-6C each illustrate an internal side view of a shutoff valve in accordance with embodiments of the present invention in different operating positions
- FIG. 7A-7C each illustrate an internal side view of an alternative shutoff valve in accordance with embodiments of the present invention in different operating positions
- FIGS. 8A and 8B each illustrate an internal side view of an alternative shutoff valve in accordance with embodiments of the present invention in different operating positions
- FIGS. 9A and 9B each illustrate an internal side view of an alternative shutoff valve in accordance with embodiments of the present invention in different operating positions
- FIGS. 10A-10G illustrate a progression of debris removal from a shutoff valve 100 in accordance with embodiments of the present invention.
- FIGS. 1A-10G specific embodiments, e.g., versions or examples, of a shutoff valve are illustrated. These figures may show features which may be found in various specific embodiments, including the embodiments shown in this specification and those not shown.
- FIGS. 1A-1C each illustrate a portion of a production string 2 , a primary conduit through which reservoir fluids are produced to surface.
- production string 2 may be configured and/or assembled with various tubing and completion components.
- production string 2 may be configured for gas lift application and comprise, without limitation, tubing 4 , an artificial lift completion such as a gas lift mandrel 6 , an on-off tool 8 , a retrievable production packer 10 , or any combinations thereof.
- FIG. 1A production string 2 may be configured for gas lift application and comprise, without limitation, tubing 4 , an artificial lift completion such as a gas lift mandrel 6 , an on-off tool 8 , a retrievable production packer 10 , or any combinations thereof.
- FIG. 1A production string 2 may be configured for gas lift application and comprise, without limitation, tubing 4 , an artificial lift completion such as a gas lift mandrel 6 , an on-off tool 8 , a retrievable production packer 10 , or any combinations thereof.
- production string 2 may be configured for electric submersible pump (ESP) application and comprise, without limitation, tubing 4 , an artificial lift completion such as an ESP 12 , retrievable production packer 10 , or any combinations thereof.
- production string 2 may comprise a shutoff valve 100 , a flow actuated device that creates a down hole barrier to prevent loss of kill fluid into a reservoir or formation when downhole flow may be reversed, for instance when production may be stopped. Loss of said kill fluid could damage the reservoir and/or formation.
- shutoff valve 100 may be installed at any suitable location on production string 2 . As illustrated in both FIGS.
- shutoff valve 100 may be installed below (further downhole) gas lift mandrel 6 or ESP 12 as well as below retrievable production packer 10 .
- shutoff valve 100 may be installed above (further uphole) gas lift mandrel 6 or ESP 12 as well as above retrievable production packer 10 .
- shutoff valve 100 may be installed below gas lift mandrel 6 or ESP 12 and above retrievable production packer 10 , as illustrated in FIG. 1C .
- shutoff valve 100 may comprise a fish neck 3 and flow ports 5 .
- shutoff valve 100 may be installed on new or existing completion strings of various tubing sizes, which in turn may govern the size of shutoff valve 100 .
- Standard tubing size (measured from an outer diameter) may range from about 23 ⁇ 8 inches to about 41 ⁇ 2 inches. In embodiments, the tubing size may be 27 ⁇ 8 inches, 31 ⁇ 2 inches, or 41 ⁇ 2 inches.
- shutoff valve 100 may be manufactured in a range of suitable sizes, comprising an outer diameter between about 4 inches and about 8 inches and an inner diameter between about 2 inches and about 4 inches.
- shutoff valve 100 when employed on a completion string using tubing sized to 2% inches, may comprise an outer diameter measuring about 4.65 inches and an inner diameter measuring about 2.31 inches.
- shutoff valve 100 when employed on a completion string using tubing sized to 31 ⁇ 2 inches, may comprise an outer diameter measuring about 5.20 inches and an inner diameter measuring about 2.75 inches.
- shutoff valve 100 when employed on a completion string with tubing sized to 41 ⁇ 2 inches, may comprise an outer diameter measuring about 7.20 inches and an inner diameter measuring about 3.75 inches. Depending on tubing size, shutoff valve 100 may be rated for high pressures between about 5,000 psi to about 15,000 psi. In embodiments, shutoff valve 100 may be rated for pressures up to 10,000 psi. Further, shutoff valve 100 may be rated for standard and high temperatures between about 300° F. and about 700° F. In embodiments, shutoff valve may be rated for a standard temperature of about 350° F., or alternatively for a high temperature of about 600° F. Regardless of the tubing size, shutoff valve 100 may be manufactured to any suitable axial length, ranging from about 25 inches to about 45 inches. In embodiments, the overall axial length of shutoff valve 100 may be about 35 inches.
- FIG. 2 illustrates an internal side view of an embodiment of shutoff valve 100 .
- Shutoff valve 100 may comprise a top sub 102 , a bottom sub 104 , a flow tube 106 , and a flapper valve 126 .
- top sub 102 and bottom sub 104 may be hollow-bodied metal components coupled together via any suitable fastening mechanisms, thereby forming a borehole 118 through which fluid may flow.
- Top sub 102 and/or bottom sub 104 may be manufactured from any oil field steel.
- top sub 102 and/or bottom sub 104 may be manufactured from L-80 Steel, P-110 Steel, 9 Chrome, 13 Chrome, etc.
- suitable fastening mechanisms may comprise, without limitation, a threaded fastener 122 , shear screws 124 , or any combinations thereof.
- Threaded fastener 122 may comprise female/internal threading disposed on a portion of the interior surface of top sub 102 as well as corresponding male/external threading disposed on a portion of the exterior surface of bottom sub 104 , thus providing a means by which bottom sub 104 may be screwed into top sub 102 .
- the male/external threading of threaded fastener 122 as well as some other components may be further depicted in FIG. 3 , illustrating a perspective view of a portion of bottom sub 104 .
- threaded fastener 122 may comprise a 4- 5/16-inch diameter, 8 thread per inch, ACME thread with a class 2G. In other embodiments, other thread types may be employed. Referring once again to FIG. 2 , a top portion of bottom sub 104 may be screwed into a bottom portion of top sub 102 via threaded fastener 122 until the bottom portion of top sub 102 engages a flange 116 of bottom sub 104 . In conjunction with or independent of threaded fastener 122 , shear screws 124 may be employed to connect top sub 102 to bottom sub 104 .
- shear screws 124 may be threaded through top sub 102 and bottom sub 104 in a radial direction at a point at which the bottom portion of top sub 102 overlaps with the top portion of bottom sub 104 . Shear screws 124 may allow for shearing between top sub 102 and bottom sub 104 in the event of emergency or malfunction of shutoff valve 100 , such as an inadvertent obstruction of fluid flow through borehole 118 . Shearing may be performed by applying a pressure to shutoff valve 100 that exceeds its overall pressure rating.
- shutoff valve 100 may further comprise a sealing element 132 disposed radially between top sub 102 and bottom sub 104 at the point at which the bottom portion of top sub 102 overlaps with the top portion of bottom sub 104 .
- Sealing element 132 may be any suitable sealing mechanism such as, without limitation, an O-ring or the like, which may be capable of preventing fluid leakage from borehole 118 .
- borehole 118 may comprise upper and lower portions 119 and 121 , each having a diameter corresponding to that of the tubing utilized in the completion string on which shutoff valve 100 may be installed (i.e., the inner diameter of shutoff valve 100 ). Further, borehole 118 may comprise a middle portion 123 having a variable diameter greater than that of upper and lower portions 119 and 121 .
- middle portion 123 may contain flow tube 106 , a hollow-bodied metal cylinder comprising a flow tube borehole through which fluid flowing through borehole 118 may pass.
- flow tube 106 may be sized to fit within middle portion 123 , such that the flow tube borehole may be in-line with upper and lower portions 119 and 121 , as well as correspond in diameter to that of upper and lower portions 119 and 121 .
- flow tube 106 may be sized, particularly in length, to be capable of axial movement within middle portion 123 .
- embodiments of flow tube 106 may be outfitted with an orifice disk 146 by any suitable means.
- Orifice disk 146 may be a bi-directional actuator of a single, circular component attached over a bottom opening of flow tube 106 via screws 148 , thus providing a partial covering of the bottom opening.
- orifice disk 146 may be mad up of proprietary fiber-infused, erosion-resistant material such as, without limitation, rubber materials.
- FIGS. 4A-4D illustrate different embodiments of orifice disk 146 with one or more holes 149 to receive screws 148 .
- orifice disk 146 may comprise an opening 147 and any suitable number of flexible flaps 152 .
- FIG. 4A illustrates an embodiment of orifice disk 146 comprising opening 147 and six flexible flaps 152
- FIG. 4B illustrates an embodiment of orifice disk 146 comprising opening 147 and three flexible flaps 152
- FIG. 4C illustrates an embodiment of orifice disk 146 comprising opening 147 and four flexible flaps 152 .
- FIG. 4D as opposed to FIGS.
- opening 147 may not initially comprise opening 147 , but rather may only initially comprise three flexible flaps 152 , in addition to holes 149 .
- opening 147 may be revealed through spacing in flexible flaps 152 caused by the fluid flow.
- Orifice disk 146 having flexibility by nature of material, may allow for fluid to flow through opening 147 and flexible flaps 152 at the bottom opening of flow tube 106 and manipulate the axial movement of flow tube 106 . Further, orifice disk 146 , having durability by nature of material, may experience minimal erosion that could otherwise be caused by the flowing fluid.
- middle portion 123 may further contain flapper valve 126 , a circular metal flapper capable of obstructing fluid flow within borehole 118 .
- flapper valve 126 may be sized, particularly in area, to be seated on a valve seat 136 comprising a sealing element 134 , and further may be disposed on a top surface of bottom sub 104 . As such, flapper valve 126 may be capable of fully covering a top opening of flow tube 106 .
- flapper valve 126 may be connected to the top surface of bottom sub 104 via a hinge pin connection 141 comprising a hinge pin 140 and a spring 138 (e.g., a torsion spring, a compression spring, a tension spring, or the like) to allow for hinged movement of flapper valve 126 within middle portion 123 .
- flapper valve 126 may be capable of moving between a fully opened position and a fully closed position.
- the fully opened position may comprise flapper valve 126 being positioned at about a 90° angle relative to the top surface of bottom sub 104 within a flapper valve recess 125 of middle portion 123
- the fully closed position may comprise flapper valve 126 being positioned at about a 0° angle relative to the top surface of bottom sub 104 , in complete contact with valve seat 136 .
- Alternate embodiments of flapper valve 126 and valve seat 136 may be illustrated in FIGS. 5A and 5B .
- FIG. 5A illustrates an angled flapper valve 126 comprising an angled edge 127 to correspondingly mate with angled valve seat 136 .
- flapper valve 126 capable of mating with a ridged valve seat 136 comprising a ridge 137 .
- flapper valve 126 may be any shape suitable for properly mating with valve seat 136 such as, without limitation, straight, convex, and/or concaved, as it relates to fluid flow in the downhole direction.
- FIGS. 6A-6C illustrate various positions in which shutoff valve 100 may operate.
- FIG. 6A which is the same as FIG. 2 described above, illustrates shutoff valve 100 in an initial resting position during operation. In this position, flow tube 106 , through the assistance of gravity, may be disposed below flapper valve 126 such that the bottom of flow tube 106 may be resting on a lower ledge 130 . Lower ledge 130 may provide a means in which to prevent any further downward axial movement of flow tube 106 during operation.
- flapper valve 126 through the assistance of spring 138 , may be biased in a partially opened position at about a 45° angle relative to the top surface of bottom sub 104 . In this position, there may be minimal or no fluid flowing through borehole 118 .
- FIG. 6B illustrates shutoff valve 100 in a fully opened position during operation.
- flow tube 106 may be disposed such that the top opening may be in contact with an upper ledge 120 and an outer portion of orifice disk 146 disposed at the bottom opening of flow tube 106 may be in contact with a middle ledge 131 .
- the contact between the outer portion of orifice disk 146 and middle ledge 131 may aid in preventing fluid from leaking into an annulus between flow tube 106 and top and bottom subs 102 and 104 .
- Upper ledge 120 and middle ledge 131 may provide a means in which to prevent any further upward axial movement of flow tube 106 during operation.
- flapper valve 126 may be in the fully opened position.
- This positioning of flow tube 106 and flapper valve 126 may be caused by fluid flowing upward through borehole 118 , toward the surface of the well.
- the upward flowing fluid may engage with flexible flaps 152 of orifice disk 146 , pushing flexible flaps 152 toward the surface of the well, thereby forcing flow tube 106 to move axially upward until reaching upper ledge 120 and middle ledge 131 .
- fluid may continuously flow through borehole 118 , passing through opening 147 of orifice disk 146 , which includes any space created by the displacement of flexible flaps 152 , as well as through the flow tube borehole. This may occur with a minimal pressure drop of less than 3 psi.
- flapper valve 126 may be isolated from the upward flowing fluid, thus preventing any erosion to flapper valve 126 that may otherwise be caused by the upward flowing fluid.
- FIG. 6C illustrates shutoff valve 100 in a fully closed position.
- flow tube 106 may be disposed below flapper valve 126 such that the bottom of flow tube 106 may be resting on lower ledge 130 .
- flapper valve 126 may be in the fully closed position, thus preventing any fluid flow within borehole 118 .
- This positioning of flow tube 106 and flapper valve 126 may be caused by fluid flowing downward through borehole 118 , in a downhole direction. The downward flowing fluid may engage with flexible flaps 152 of orifice disk 146 , pushing flexible flaps 152 downward, thereby forcing flow tube 106 to move axially downward until reaching lower ledge 130 .
- sealing element 134 may provide an initial seal for flapper valve 126 until load from the pressure differential of the downward flowing fluid creates a metal-to-metal seal between flapper valve 126 and valve seat 136 . In this position, fluid flow within borehole 118 may be halted, thus preventing any kill fluid from flowing back into the formation, particularly when production has stopped. This may reduce potential reservoir damage due to fluid loss.
- FIGS. 7A-7C illustrate an alternative embodiment of shutoff valve 100 .
- shutoff valve 100 may comprise an alternative flow tube 111 , which may be similar to that of flow tube 106 , but comprises a drag section 154 rather than orifice disk 146 .
- Drag section 154 may be a section of flow tube 111 of smaller inner diameter or smaller inner and outer diameter comprising one or more surface-facing drags 156 and one or more downhole-facing drags 158 .
- drag section 154 may provide similar functionality for shutoff valve 100 as that of orifice disk 146 .
- FIG. 7A illustrates shutoff valve 100 in an initial resting position during operation.
- flow tube 111 through the assistance of gravity, may be disposed below flapper valve 126 such that the bottom of flow tube 111 may be resting on lower ledge 130 .
- Lower ledge 130 may provide a means in which to prevent any further downward axial movement of flow tube 111 during operation.
- flapper valve 126 through the assistance of spring 138 , may be biased in a partially opened position at about a 45° angle relative to the top surface of bottom sub 104 . In this position, there may be minimal or no fluid flowing through borehole 118 .
- FIG. 7B illustrates shutoff valve 100 in a fully opened position during operation.
- flow tube 111 may be disposed such that the top opening may be in contact with upper ledge 120 .
- Upper ledge 120 may provide a means in which to prevent any further upward axial movement of flow tube 111 during operation.
- flapper valve 126 may be in the fully opened position. This positioning of flow tube 111 and flapper valve 126 may be caused by fluid flowing upward through borehole 118 , toward the surface of the well. The upward flowing fluid may engage with downhole-facing drag 158 , thereby forcing flow tube 111 to move axially upward until reaching upper ledge 120 . In this position, fluid may continuously flow through borehole 118 , passing through the flow tube borehole. This may occur with a minimal pressure drop of less than 3 psi. Further in this position, flapper valve 126 may be isolated from the upward flowing fluid, thus preventing any erosion to flapper valve 126 that may otherwise be caused by the upward flowing fluid.
- FIG. 7C illustrates shutoff valve 100 in a fully closed position.
- flow tube 111 may be disposed below flapper valve 126 such that the bottom of flow tube 111 may be resting on lower ledge 130 .
- flapper valve 126 may be in the fully closed position, thus preventing any fluid flow within borehole 118 .
- This positioning of flow tube 111 and flapper valve 126 may be caused by fluid flowing downward through borehole 118 , in a downhole direction. The downward flowing fluid may engage with surface-facing drag 156 , thereby forcing flow tube 111 to move axially downward until reaching lower ledge 130 .
- sealing element 134 may provide an initial seal for flapper valve 126 until load from the pressure differential of the downward flowing fluid creates a metal-to-metal seal between flapper valve 126 and valve seat 136 . In this position, fluid flow within borehole 118 may be halted, thus preventing any kill fluid from flowing back into the formation, particularly when production has stopped. This may reduce potential reservoir damage due to fluid loss.
- FIGS. 8A and 8B illustrate an alternative embodiment of shutoff valve 100 .
- shutoff valve 100 may comprise an alternative flow tube 107 , which may be similar to that of flow tube 106 , but further comprise flow tube notch 166 .
- shutoff valve 100 may comprise a flow tube spring 160 , a compression spring disposed radially between flow tube 107 and bottom sub 104 and axially between movable spring guard 162 and stationary spring guard 164 .
- bottom sub 104 may consist of two parts 103 and 105 coupled together by any suitable fastening mechanisms as previously described.
- flow tube spring 160 may be radially disposed between flow tube 107 and bottom sub part 103 .
- FIG. 8A illustrates alternative shutoff valve 100 in an initial resting position/fully opened position during operation.
- spring 160 may bias flow tube 107 such that the top opening may be in contact with upper ledge 120 , an outer portion of orifice disk 146 may be in contact with middle ledge 131 , and a connection point 143 between orifice disk 146 and flow tube 107 may be in contact with stationary spring guard 164 .
- the contact between the outer portion of orifice disk 146 and middle ledge 131 may aid in preventing fluid from leaking into an annulus between flow tube 107 and top and bottom subs 102 and 104 .
- Upper ledge 120 and middle ledge 131 may provide a means in which to prevent any further upward axial movement of flow tube 107 during operation.
- flapper valve 126 may be in the fully opened position. This positioning of flow tube 107 and flapper valve 126 may be caused or assisted by decompression of flow tube spring 160 , which may be capable of applying an upward force through movable spring guard 132 to flow tube notch 166 , particularly when there may be minimal or no fluid flowing through borehole 118 , or rather when fluid may be flowing upward through borehole 118 , toward the surface of the well. Similar to previous embodiments, in this position, fluid may continuously flow through borehole 118 , passing through opening 147 of orifice disk 146 , which includes any space created by the displacement of flexible flaps 152 , as well as through the flow tube borehole. This may occur with a minimal pressure drop of less than 3 psi. Further in this position, flapper valve 126 may be isolated from the upward flowing fluid, thus preventing any erosion to flapper valve 126 that may otherwise be caused by the upward flowing fluid.
- FIG. 8B illustrates alternative shutoff valve 100 in a fully closed position during operation.
- downward flowing fluid may bias flow tube 107 below flapper valve 126 such that the bottom of flow tube 107 may be resting on lower ledge 130 .
- flapper valve 126 may be in the fully closed position.
- This positioning of flow tube 107 and flapper valve 126 may be caused or assisted by fluid flowing downward through borehole 118 , in a downhole direction.
- the downward flowing fluid may engage with flexible flaps 152 of orifice disk 146 , pushing flexible flaps 152 downward, thereby forcing flow tube 107 to move axially downward until reaching lower ledge 130 .
- flow tube notch 166 may apply a downward force to movable spring guard 162 thereby axially displacing movable spring guard 162 in the downward direction and compressing spring 160 between movable spring guard 162 and stationary spring guard 164 .
- the downward flowing fluid may engage with a top side of flapper valve 126 , pushing flapper valve 126 into valve seat 136 .
- sealing element 134 may provide an initial seal for flapper valve 126 until load from the pressure differential of the downward flowing fluid creates a metal-to-metal seal between flapper valve 126 and valve seat 136 . In this position, fluid flow within borehole 118 may be halted, thus preventing any kill fluid from flowing back into the formation, particularly when production has stopped. This may reduce potential reservoir damage due to fluid loss.
- FIGS. 9A and 9B illustrate an alternative embodiment of shutoff valve 100 .
- shutoff valve 100 may comprise an alternative flow tube 109 , which may be similar to that of flow tube 107 , but further comprise an orifice disk extension piece 145 .
- orifice disk 146 may be attached to a bottom opening of orifice disk extension piece 145 via screws 148 , while orifice disk extension piece 145 may in turn be attached to flow tube 109 by any suitable means, such as screws 129 .
- flow tube 109 may function similarly to that of flow tube 107 , as is illustrated in FIGS. 9A and 9B .
- FIG. 9A illustrates alternative shutoff valve 100 in an initial resting position/fully opened position during operation.
- spring 160 may bias flow tube 109 such that the top opening may be in contact with upper ledge 120 and a connection point 171 between orifice disk extension piece 145 and flow tube 109 may be in contact with stationary spring guard 164 .
- Upper ledge 120 and stationary spring guard 164 may provide a means in which to prevent any further upward axial movement of flow tube 109 during operation.
- flapper valve 126 may be in the fully opened position.
- this positioning of flow tube 109 and flapper valve 126 may be caused or assisted by decompression of flow tube spring 160 , which may be capable of applying an upward force through movable spring guard 132 to flow tube notch 166 , particularly when there may be minimal or no fluid flowing through borehole 118 , or rather when fluid may be flowing upward through borehole 118 , toward the surface of the well.
- fluid may continuously flow through borehole 118 , passing through opening 147 of orifice disk 146 , which includes any space created by the displacement of flexible flaps 152 , as well as through the flow tube borehole. This may occur with a minimal pressure drop of less than 3 psi.
- flapper valve 126 may be isolated from the upward flowing fluid, thus preventing any erosion to flapper valve 126 that may otherwise be caused by the upward flowing fluid.
- FIG. 9B illustrates alternative shutoff valve 100 in a fully closed position during operation.
- downward flowing fluid may bias flow tube 109 below flapper valve 126 .
- flapper valve 126 may be in the fully closed position. Similar to previous embodiments, this positioning of flow tube 109 and flapper valve 126 may be caused or assisted by fluid flowing downward through borehole 118 , in a downhole direction. The downward flowing fluid may engage with flexible flaps 152 of orifice disk 146 , pushing flexible flaps 152 downward, thereby forcing flow tube 109 to move axially downward until below closed flapper valve 126 .
- flow tube notch 166 may apply a downward force to movable spring guard 162 thereby axially displacing movable spring guard 162 in the downward direction and compressing spring 160 between movable spring guard 162 and stationary spring guard 164 .
- the downward flowing fluid may engage with a top side of flapper valve 126 , pushing flapper valve 126 into valve seat 136 .
- Sealing element 134 may provide an initial seal for flapper valve 126 until load from the pressure differential of the downward flowing fluid creates a metal-to-metal seal between flapper valve 126 and valve seat 136 . In this position, fluid flow within borehole 118 may be halted, thus preventing any kill fluid from flowing back into the formation, particularly when production has stopped. This may reduce potential reservoir damage due to fluid loss.
- orifice disk extension piece 145 may be implemented on any one of the previous flow tube embodiments.
- shutoff valve 100 illustrated in FIGS. 9A and 9B may further comprise a pump-open sleeve 170 .
- Pump-open sleeve 170 may be a sleeve disposed about an outer surface of top sub 102 covering openings 172 , which may lead from borehole 118 to outside shutoff valve 100 .
- pump-open sleeve 170 may be attached to top sub 102 via shear screws 176 .
- sealing elements 174 may be disposed radially between top sub 102 and pump-open sleeve 170 to aid in sealing off openings 172 .
- openings 172 may be disposed through top sub 102 in any suitable size, shape, and number, and may provide a means by which to clean out any built-up debris from above a fully closed flapper valve 126 . Debris buildup may prevent shutoff valve 100 from moving to the fully open position after having been previously closed, thus may inadvertently restrict fluid flow within borehole 118 .
- FIGS. 10A-10G illustrate a progression of debris removal from an embodiment of shutoff valve 100 comprising pump-open sleeve 170 and experiencing a buildup of debris 180 .
- FIG. 10A illustrates an initial state of shutoff valve 100 experiencing a buildup of debris 180 in a fully closed position.
- an operator may apply a differential pressure (depicted by arrows 182 ) to shutoff valve 100 in the downhole direction.
- This applied differential pressure may be capable actuating pump-open sleeve 170 by shearing shear screws 176 , thereby permanently uncovering openings 172 .
- At least a portion of debris 180 may be displaced from inside borehole 118 through openings 172 .
- This displacement of debris 180 may allow at least some fluid flow (depicted by arrows 184 ) to be restored through openings 172 .
- the removal of debris 180 from above flapper valve 126 may also continue.
- enough debris 180 may be removed so as to allow shutoff valve 100 to move to the fully open position and thereby allow, once again, upward fluid flow through borehole 118 , as well as through openings 172 .
- shutoff valve 100 may no longer be capable of moving to the fully closed position. In order to recover this functionality, an operator may need to retrieve shutoff valve 100 and redress the tool. Although only depicted in FIGS. 8A-9G , pump-open sleeve 170 may be implemented on any one of the previous shutoff valve embodiments.
- shutoff valve 100 may be that it deals with some common problems in wellbore production.
- the unobstructed downward flow of fluid may allow the pumping mechanism (e.g., an ESP or gas lift) to move in reverse, which could lead to damage of the pump. This may be especially true if an operator attempts to restart the pump while the pumping mechanism may already be moving in reverse.
- Another problem may be that unobstructed downward flow of fluid would be permitted to uncontrollably move back into the formation, which could cause serious issues with the productivity of the well.
- unwanted upward fluid flow may be allowed to flow freely toward the surface of a well.
- shutoff valve 100 may be reciprocally installed, thus capable of preventing unwanted upward fluid flow. Regardless of orientation, the advantages of the embodiments of shutoff valve 100 may be that it self-operates without the need for control lines or external actuation signals, as well as reduces rig time by maintaining static fluid level created by the downhole barrier.
Abstract
A shutoff valve device for permitting and preventing fluid flow in a production string. In one embodiments, the shutoff valve device comprising: a body comprising a borehole, wherein the body is a top sub coupled to a bottom sub via a threaded fastener; a flow tube disposed within the body's borehole and capable of axial movement within the body's borehole, comprising a flow tube borehole; a bi-directional actuator attached to a bottom opening of the flow tube, comprising flexible flaps; and a flapper valve disposed within the body's borehole, wherein the flapper valve is hingedly coupled to a top surface of the bottom sub and capable of moving between a fully opened and fully closed position.
Description
- This application is a non-provisional application that claims the benefit of U.S. Application Ser. No. 63/065,864 filed Aug. 14, 2020, the disclosure of which are incorporated by reference herein in their entirety.
- Not applicable.
- The field of this application and any resulting patent is an improved valve, and in particular, but not exclusively, to improvements in and relating to a downhole shutoff valve.
- Various systems and methods have been proposed and utilized for preventing fluids from flowing back into a formation once production is stopped, including some of the systems and methods in the references appearing on the face of this patent. However, those systems and methods lack all the steps or features of the systems and methods covered by any patent claims below. As will be apparent to a person of ordinary skill in the art, any systems and methods covered by claims of the issued patent solve many of the problems that prior art systems and methods have failed to solve. Also, the systems and methods covered by at least some of the claims of this patent have benefits that could be surprising and unexpected to a person of ordinary skill in the art based on the prior art existing at the time of invention.
- One or more specific embodiments disclosed herein includes a shutoff valve device that may comprise a top sub, a bottom sub, and a flow tube, wherein the bottom sub may comprise a flapper valve and a valve seat, and further wherein the flow tube may comprise drag features designed to move the flow tube back and forth from a first position (holding the flapper valve in a completely open position) to a second position (allowing the flapper valve to a closed, sealed position), depending on the direction of fluid flow in the wellbore.
- One or more specific embodiments disclosed herein includes a shutoff valve device for permitting and preventing fluid flow in a production string, comprising: a body comprising a borehole, wherein the body is a top sub coupled to a bottom sub via a threaded fastener; a flow tube disposed within the body's borehole and capable of axial movement within the body's borehole, comprising a flow tube borehole; a bi-directional actuator attached to a bottom opening of the flow tube, comprising flexible flaps; and a flapper valve disposed within the body's borehole, wherein the flapper valve is hingedly coupled to a top surface of the bottom sub and capable of moving between a fully opened and fully closed position.
- One or more specific embodiments disclosed herein includes a shutoff valve device for permitting and preventing fluid flow in a production string, comprising: a body comprising a borehole, wherein the body is a top sub coupled to a bottom sub via a threaded fastener; a flow tube disposed within the body's borehole and capable of axial movement within the body's borehole, comprising a flow tube borehole; a compression spring disposed radially between the flow tube and the body, wherein the compression spring biases the flow tube in an axially upward position; a bi-directional actuator attached to a bottom opening of the flow tube, comprising flexible flaps; and a flapper valve disposed within the body's borehole, wherein the flapper valve is hingedly coupled to a top surface of the bottom sub and capable of moving between a fully opened and fully closed position.
- One or more specific embodiments disclosed herein includes a method for permitting and preventing fluid flow in a production string, comprising: outfitting a production string with a shutoff valve device comprising: a body comprising a borehole, wherein the body is a top sub coupled to a bottom sub via a threaded fastener; a flow tube disposed within the body's borehole and capable of axial movement within the body's borehole, comprising a flow tube borehole; a bi-directional actuator attached to a bottom opening of the flow tube, comprising flexible flaps; and a flapper valve disposed within the body's borehole, wherein the flapper valve is hingedly coupled to a top surface of the bottom sub and capable of moving between a fully opened and fully closed position.
- The foregoing has outlined rather broadly the features and technical advantages of the present invention in order that the detailed description of the invention that follows may be better understood. Additional features and advantages of the invention will be described hereinafter that form the subject of the claims of the invention. It should be appreciated by those skilled in the art that the conception and the specific embodiments disclosed may be readily utilized as a basis for modifying or designing other embodiments for carrying out the same purposes of the present invention. It should also be realized by those skilled in the art that such equivalent embodiments do not depart from the spirit and scope of the invention as set forth in the appended claims.
- For a detailed description of the preferred embodiments of the invention, reference will now be made to the accompanying drawings in which:
-
FIG. 1A-1C each illustrate a portion of a production string configured with a shutoff valve in accordance with embodiments of the present invention; -
FIG. 2 illustrates an internal side view of a shutoff valve in accordance with embodiments of the present invention; -
FIG. 3 illustrates a perspective view of a portion of a bottom sub of a shutoff valve in accordance with embodiments of the present invention; -
FIGS. 4A-4D each illustrate an orifice disk in accordance with embodiments of the present invention; -
FIGS. 5A and 5B each illustrate an internal side view of an alternative flapper valve in accordance with embodiments of the present invention; -
FIG. 6A-6C each illustrate an internal side view of a shutoff valve in accordance with embodiments of the present invention in different operating positions; -
FIG. 7A-7C each illustrate an internal side view of an alternative shutoff valve in accordance with embodiments of the present invention in different operating positions; -
FIGS. 8A and 8B each illustrate an internal side view of an alternative shutoff valve in accordance with embodiments of the present invention in different operating positions; -
FIGS. 9A and 9B each illustrate an internal side view of an alternative shutoff valve in accordance with embodiments of the present invention in different operating positions; -
FIGS. 10A-10G illustrate a progression of debris removal from ashutoff valve 100 in accordance with embodiments of the present invention. - A detailed description will now be provided. The purpose of this detailed description, which includes the drawings, is to satisfy the statutory requirements of 35 U.S.C. § 112. For example, the detailed description includes a description of the inventions defined by the claims and sufficient information that would enable a person having ordinary skill in the art to make and use the inventions. In the figures, like elements are generally indicated by like reference numerals regardless of the view or figure in which the elements appear. The figures are intended to assist the description and to provide a visual representation of certain aspects of the subject matter described herein. The figures are not all necessarily drawn to scale, nor do they show all the structural details of the systems, nor do they limit the scope of the claims.
- Each of the appended claims defines a separate invention which, for infringement purposes, is recognized as including equivalents of the various elements or limitations specified in the claims. Depending on the context, all references below to the “invention” may in some cases refer to certain specific embodiments only. In other cases, it will be recognized that references to the “invention” will refer to the subject matter recited in one or more, but not necessarily all, of the claims. Each of the inventions will now be described in greater detail below, including specific embodiments, versions, and examples, but the inventions are not limited to these specific embodiments, versions, or examples, which are included to enable a person having ordinary skill in the art to make and use the inventions when the information in this patent is combined with available information and technology.
- The drawings presented herein are for illustrative purposes only and are not intended to limit the scope of the claims. Rather, the drawings are intended to help enable one having ordinary skill in the art to make and use the claimed inventions.
- Referring to
FIGS. 1A-10G , specific embodiments, e.g., versions or examples, of a shutoff valve are illustrated. These figures may show features which may be found in various specific embodiments, including the embodiments shown in this specification and those not shown. -
FIGS. 1A-1C each illustrate a portion of aproduction string 2, a primary conduit through which reservoir fluids are produced to surface. Depending on wellbore conditions and desired production method,production string 2 may be configured and/or assembled with various tubing and completion components. As illustrated inFIG. 1A ,production string 2 may be configured for gas lift application and comprise, without limitation,tubing 4, an artificial lift completion such as agas lift mandrel 6, an on-off tool 8, aretrievable production packer 10, or any combinations thereof. Alternatively, as illustrated inFIG. 1B ,production string 2 may be configured for electric submersible pump (ESP) application and comprise, without limitation,tubing 4, an artificial lift completion such as anESP 12,retrievable production packer 10, or any combinations thereof. In addition to the various completion components,production string 2 may comprise ashutoff valve 100, a flow actuated device that creates a down hole barrier to prevent loss of kill fluid into a reservoir or formation when downhole flow may be reversed, for instance when production may be stopped. Loss of said kill fluid could damage the reservoir and/or formation. In embodiments,shutoff valve 100 may be installed at any suitable location onproduction string 2. As illustrated in bothFIGS. 1A and 1B ,shutoff valve 100 may be installed below (further downhole)gas lift mandrel 6 orESP 12 as well as belowretrievable production packer 10. Alternatively, although not illustrated,shutoff valve 100 may be installed above (further uphole)gas lift mandrel 6 orESP 12 as well as aboveretrievable production packer 10. Further alternatively,shutoff valve 100 may be installed belowgas lift mandrel 6 orESP 12 and aboveretrievable production packer 10, as illustrated inFIG. 1C . In such an embodiment,shutoff valve 100 may comprise a fish neck 3 and flowports 5. - In embodiments,
shutoff valve 100 may be installed on new or existing completion strings of various tubing sizes, which in turn may govern the size ofshutoff valve 100. Standard tubing size (measured from an outer diameter) may range from about 2⅜ inches to about 4½ inches. In embodiments, the tubing size may be 2⅞ inches, 3½ inches, or 4½ inches. Depending on the tubing size,shutoff valve 100 may be manufactured in a range of suitable sizes, comprising an outer diameter between about 4 inches and about 8 inches and an inner diameter between about 2 inches and about 4 inches. Note that the outer diameter may be measure from the point of greatest outer diameter ofshutoff valve 100 and the inner diameter may be measured from the point of smallest inner diameter ofshutoff valve 100, particularly in embodiments in which the outer and inner diameters ofshutoff valve 100 may be variable along the axial length. In embodiments,shutoff valve 100, when employed on a completion string using tubing sized to 2% inches, may comprise an outer diameter measuring about 4.65 inches and an inner diameter measuring about 2.31 inches. Alternatively,shutoff valve 100, when employed on a completion string using tubing sized to 3½ inches, may comprise an outer diameter measuring about 5.20 inches and an inner diameter measuring about 2.75 inches. Further alternatively,shutoff valve 100, when employed on a completion string with tubing sized to 4½ inches, may comprise an outer diameter measuring about 7.20 inches and an inner diameter measuring about 3.75 inches. Depending on tubing size,shutoff valve 100 may be rated for high pressures between about 5,000 psi to about 15,000 psi. In embodiments,shutoff valve 100 may be rated for pressures up to 10,000 psi. Further,shutoff valve 100 may be rated for standard and high temperatures between about 300° F. and about 700° F. In embodiments, shutoff valve may be rated for a standard temperature of about 350° F., or alternatively for a high temperature of about 600° F. Regardless of the tubing size,shutoff valve 100 may be manufactured to any suitable axial length, ranging from about 25 inches to about 45 inches. In embodiments, the overall axial length ofshutoff valve 100 may be about 35 inches. -
FIG. 2 illustrates an internal side view of an embodiment ofshutoff valve 100.Shutoff valve 100 may comprise atop sub 102, abottom sub 104, aflow tube 106, and aflapper valve 126. In embodiments,top sub 102 andbottom sub 104 may be hollow-bodied metal components coupled together via any suitable fastening mechanisms, thereby forming a borehole 118 through which fluid may flow.Top sub 102 and/orbottom sub 104 may be manufactured from any oil field steel. For example,top sub 102 and/orbottom sub 104 may be manufactured from L-80 Steel, P-110 Steel, 9 Chrome, 13 Chrome, etc. In embodiments, suitable fastening mechanisms may comprise, without limitation, a threadedfastener 122, shear screws 124, or any combinations thereof. Threadedfastener 122 may comprise female/internal threading disposed on a portion of the interior surface oftop sub 102 as well as corresponding male/external threading disposed on a portion of the exterior surface ofbottom sub 104, thus providing a means by whichbottom sub 104 may be screwed intotop sub 102. The male/external threading of threadedfastener 122 as well as some other components may be further depicted inFIG. 3 , illustrating a perspective view of a portion ofbottom sub 104. In some embodiments, threadedfastener 122 may comprise a 4- 5/16-inch diameter, 8 thread per inch, ACME thread with a class 2G. In other embodiments, other thread types may be employed. Referring once again toFIG. 2 , a top portion ofbottom sub 104 may be screwed into a bottom portion oftop sub 102 via threadedfastener 122 until the bottom portion oftop sub 102 engages aflange 116 ofbottom sub 104. In conjunction with or independent of threadedfastener 122, shear screws 124 may be employed to connecttop sub 102 tobottom sub 104. In embodiments, shear screws 124 may be threaded throughtop sub 102 andbottom sub 104 in a radial direction at a point at which the bottom portion oftop sub 102 overlaps with the top portion ofbottom sub 104. Shear screws 124 may allow for shearing betweentop sub 102 andbottom sub 104 in the event of emergency or malfunction ofshutoff valve 100, such as an inadvertent obstruction of fluid flow throughborehole 118. Shearing may be performed by applying a pressure toshutoff valve 100 that exceeds its overall pressure rating. In some embodiments,shutoff valve 100 may further comprise asealing element 132 disposed radially betweentop sub 102 andbottom sub 104 at the point at which the bottom portion oftop sub 102 overlaps with the top portion ofbottom sub 104.Sealing element 132 may be any suitable sealing mechanism such as, without limitation, an O-ring or the like, which may be capable of preventing fluid leakage fromborehole 118. In embodiments,borehole 118 may comprise upper andlower portions shutoff valve 100 may be installed (i.e., the inner diameter of shutoff valve 100). Further,borehole 118 may comprise amiddle portion 123 having a variable diameter greater than that of upper andlower portions - As illustrated in
FIG. 2 ,middle portion 123 may containflow tube 106, a hollow-bodied metal cylinder comprising a flow tube borehole through which fluid flowing throughborehole 118 may pass. In embodiments,flow tube 106 may be sized to fit withinmiddle portion 123, such that the flow tube borehole may be in-line with upper andlower portions lower portions flow tube 106 may be sized, particularly in length, to be capable of axial movement withinmiddle portion 123. To aid in facilitating this axial movement, embodiments offlow tube 106 may be outfitted with anorifice disk 146 by any suitable means.Orifice disk 146 may be a bi-directional actuator of a single, circular component attached over a bottom opening offlow tube 106 viascrews 148, thus providing a partial covering of the bottom opening. In embodiments,orifice disk 146 may be mad up of proprietary fiber-infused, erosion-resistant material such as, without limitation, rubber materials. -
FIGS. 4A-4D illustrate different embodiments oforifice disk 146 with one ormore holes 149 to receivescrews 148. In embodiments,orifice disk 146, on addition toholes 149, may comprise anopening 147 and any suitable number offlexible flaps 152.FIG. 4A illustrates an embodiment oforifice disk 146 comprisingopening 147 and sixflexible flaps 152,FIG. 4B illustrates an embodiment oforifice disk 146 comprisingopening 147 and threeflexible flaps 152, andFIG. 4C illustrates an embodiment oforifice disk 146 comprisingopening 147 and fourflexible flaps 152.FIG. 4D , as opposed toFIGS. 4A-4C , may not initially comprise opening 147, but rather may only initially comprise threeflexible flaps 152, in addition toholes 149. For such an embodiment, it may not be untilorifice disk 146 experiences fluid flow that opening 147 may be revealed through spacing inflexible flaps 152 caused by the fluid flow.Orifice disk 146, having flexibility by nature of material, may allow for fluid to flow throughopening 147 andflexible flaps 152 at the bottom opening offlow tube 106 and manipulate the axial movement offlow tube 106. Further,orifice disk 146, having durability by nature of material, may experience minimal erosion that could otherwise be caused by the flowing fluid. - Referring to
FIG. 2 ,middle portion 123 may further containflapper valve 126, a circular metal flapper capable of obstructing fluid flow withinborehole 118. In embodiments,flapper valve 126 may be sized, particularly in area, to be seated on avalve seat 136 comprising a sealingelement 134, and further may be disposed on a top surface ofbottom sub 104. As such,flapper valve 126 may be capable of fully covering a top opening offlow tube 106. Further,flapper valve 126 may be connected to the top surface ofbottom sub 104 via ahinge pin connection 141 comprising ahinge pin 140 and a spring 138 (e.g., a torsion spring, a compression spring, a tension spring, or the like) to allow for hinged movement offlapper valve 126 withinmiddle portion 123. In embodiments,flapper valve 126 may be capable of moving between a fully opened position and a fully closed position. The fully opened position may compriseflapper valve 126 being positioned at about a 90° angle relative to the top surface ofbottom sub 104 within aflapper valve recess 125 ofmiddle portion 123, while the fully closed position may compriseflapper valve 126 being positioned at about a 0° angle relative to the top surface ofbottom sub 104, in complete contact withvalve seat 136. Alternate embodiments offlapper valve 126 andvalve seat 136 may be illustrated inFIGS. 5A and 5B .FIG. 5A illustrates anangled flapper valve 126 comprising anangled edge 127 to correspondingly mate withangled valve seat 136.FIG. 5B illustrates aflapper valve 126 capable of mating with aridged valve seat 136 comprising aridge 137. Although not exhaustively illustrated,flapper valve 126 may be any shape suitable for properly mating withvalve seat 136 such as, without limitation, straight, convex, and/or concaved, as it relates to fluid flow in the downhole direction. - In embodiments,
flow tube 106 andflapper valve 126 may operate in conjunction to permit or prevent flow throughborehole 118 ofshutoff valve 100.FIGS. 6A-6C illustrate various positions in whichshutoff valve 100 may operate.FIG. 6A , which is the same asFIG. 2 described above, illustratesshutoff valve 100 in an initial resting position during operation. In this position, flowtube 106, through the assistance of gravity, may be disposed belowflapper valve 126 such that the bottom offlow tube 106 may be resting on alower ledge 130.Lower ledge 130 may provide a means in which to prevent any further downward axial movement offlow tube 106 during operation. Further,flapper valve 126, through the assistance ofspring 138, may be biased in a partially opened position at about a 45° angle relative to the top surface ofbottom sub 104. In this position, there may be minimal or no fluid flowing throughborehole 118. -
FIG. 6B illustratesshutoff valve 100 in a fully opened position during operation. In this position, flowtube 106 may be disposed such that the top opening may be in contact with anupper ledge 120 and an outer portion oforifice disk 146 disposed at the bottom opening offlow tube 106 may be in contact with amiddle ledge 131. In embodiments, the contact between the outer portion oforifice disk 146 andmiddle ledge 131 may aid in preventing fluid from leaking into an annulus betweenflow tube 106 and top andbottom subs Upper ledge 120 andmiddle ledge 131 may provide a means in which to prevent any further upward axial movement offlow tube 106 during operation. Further,flapper valve 126 may be in the fully opened position. This positioning offlow tube 106 andflapper valve 126 may be caused by fluid flowing upward throughborehole 118, toward the surface of the well. The upward flowing fluid may engage withflexible flaps 152 oforifice disk 146, pushingflexible flaps 152 toward the surface of the well, thereby forcingflow tube 106 to move axially upward until reachingupper ledge 120 andmiddle ledge 131. In this position, fluid may continuously flow throughborehole 118, passing throughopening 147 oforifice disk 146, which includes any space created by the displacement offlexible flaps 152, as well as through the flow tube borehole. This may occur with a minimal pressure drop of less than 3 psi. Further in this position,flapper valve 126 may be isolated from the upward flowing fluid, thus preventing any erosion toflapper valve 126 that may otherwise be caused by the upward flowing fluid. -
FIG. 6C illustratesshutoff valve 100 in a fully closed position. In this position, similarly to the initial resting position, flowtube 106 may be disposed belowflapper valve 126 such that the bottom offlow tube 106 may be resting onlower ledge 130. However,flapper valve 126 may be in the fully closed position, thus preventing any fluid flow withinborehole 118. This positioning offlow tube 106 andflapper valve 126 may be caused by fluid flowing downward throughborehole 118, in a downhole direction. The downward flowing fluid may engage withflexible flaps 152 oforifice disk 146, pushingflexible flaps 152 downward, thereby forcingflow tube 106 to move axially downward until reachinglower ledge 130. Further, the downward flowing fluid may engage with a top side offlapper valve 126, pushingflapper valve 126 intovalve seat 136. In embodiments, sealingelement 134 may provide an initial seal forflapper valve 126 until load from the pressure differential of the downward flowing fluid creates a metal-to-metal seal betweenflapper valve 126 andvalve seat 136. In this position, fluid flow withinborehole 118 may be halted, thus preventing any kill fluid from flowing back into the formation, particularly when production has stopped. This may reduce potential reservoir damage due to fluid loss. -
FIGS. 7A-7C illustrate an alternative embodiment ofshutoff valve 100. In this embodiment,shutoff valve 100 may comprise analternative flow tube 111, which may be similar to that offlow tube 106, but comprises adrag section 154 rather thanorifice disk 146.Drag section 154 may be a section offlow tube 111 of smaller inner diameter or smaller inner and outer diameter comprising one or more surface-facingdrags 156 and one or more downhole-facing drags 158. In such embodiments,drag section 154 may provide similar functionality forshutoff valve 100 as that oforifice disk 146.FIG. 7A , illustratesshutoff valve 100 in an initial resting position during operation. In this position, flowtube 111, through the assistance of gravity, may be disposed belowflapper valve 126 such that the bottom offlow tube 111 may be resting onlower ledge 130.Lower ledge 130 may provide a means in which to prevent any further downward axial movement offlow tube 111 during operation. Further,flapper valve 126, through the assistance ofspring 138, may be biased in a partially opened position at about a 45° angle relative to the top surface ofbottom sub 104. In this position, there may be minimal or no fluid flowing throughborehole 118. -
FIG. 7B illustratesshutoff valve 100 in a fully opened position during operation. In this position, flowtube 111 may be disposed such that the top opening may be in contact withupper ledge 120.Upper ledge 120 may provide a means in which to prevent any further upward axial movement offlow tube 111 during operation. Further,flapper valve 126 may be in the fully opened position. This positioning offlow tube 111 andflapper valve 126 may be caused by fluid flowing upward throughborehole 118, toward the surface of the well. The upward flowing fluid may engage with downhole-facingdrag 158, thereby forcingflow tube 111 to move axially upward until reachingupper ledge 120. In this position, fluid may continuously flow throughborehole 118, passing through the flow tube borehole. This may occur with a minimal pressure drop of less than 3 psi. Further in this position,flapper valve 126 may be isolated from the upward flowing fluid, thus preventing any erosion toflapper valve 126 that may otherwise be caused by the upward flowing fluid. -
FIG. 7C illustratesshutoff valve 100 in a fully closed position. In this position, similarly to the initial resting position, flowtube 111 may be disposed belowflapper valve 126 such that the bottom offlow tube 111 may be resting onlower ledge 130. However,flapper valve 126 may be in the fully closed position, thus preventing any fluid flow withinborehole 118. This positioning offlow tube 111 andflapper valve 126 may be caused by fluid flowing downward throughborehole 118, in a downhole direction. The downward flowing fluid may engage with surface-facingdrag 156, thereby forcingflow tube 111 to move axially downward until reachinglower ledge 130. Further, the downward flowing fluid may engage with a top side offlapper valve 126, pushingflapper valve 126 intovalve seat 136. In embodiments, sealingelement 134 may provide an initial seal forflapper valve 126 until load from the pressure differential of the downward flowing fluid creates a metal-to-metal seal betweenflapper valve 126 andvalve seat 136. In this position, fluid flow withinborehole 118 may be halted, thus preventing any kill fluid from flowing back into the formation, particularly when production has stopped. This may reduce potential reservoir damage due to fluid loss. -
FIGS. 8A and 8B illustrate an alternative embodiment ofshutoff valve 100. In this embodiment,shutoff valve 100 may comprise analternative flow tube 107, which may be similar to that offlow tube 106, but further compriseflow tube notch 166. Further in this embodiment,shutoff valve 100 may comprise aflow tube spring 160, a compression spring disposed radially betweenflow tube 107 andbottom sub 104 and axially betweenmovable spring guard 162 andstationary spring guard 164. In some embodiments,bottom sub 104 may consist of twoparts tube spring 160 may be radially disposed betweenflow tube 107 andbottom sub part 103.FIG. 8A illustratesalternative shutoff valve 100 in an initial resting position/fully opened position during operation. In this position,spring 160 may bias flowtube 107 such that the top opening may be in contact withupper ledge 120, an outer portion oforifice disk 146 may be in contact withmiddle ledge 131, and aconnection point 143 betweenorifice disk 146 and flowtube 107 may be in contact withstationary spring guard 164. In embodiments, the contact between the outer portion oforifice disk 146 andmiddle ledge 131 may aid in preventing fluid from leaking into an annulus betweenflow tube 107 and top andbottom subs Upper ledge 120 andmiddle ledge 131 may provide a means in which to prevent any further upward axial movement offlow tube 107 during operation. Further,flapper valve 126 may be in the fully opened position. This positioning offlow tube 107 andflapper valve 126 may be caused or assisted by decompression offlow tube spring 160, which may be capable of applying an upward force throughmovable spring guard 132 to flowtube notch 166, particularly when there may be minimal or no fluid flowing throughborehole 118, or rather when fluid may be flowing upward throughborehole 118, toward the surface of the well. Similar to previous embodiments, in this position, fluid may continuously flow throughborehole 118, passing throughopening 147 oforifice disk 146, which includes any space created by the displacement offlexible flaps 152, as well as through the flow tube borehole. This may occur with a minimal pressure drop of less than 3 psi. Further in this position,flapper valve 126 may be isolated from the upward flowing fluid, thus preventing any erosion toflapper valve 126 that may otherwise be caused by the upward flowing fluid. -
FIG. 8B illustratesalternative shutoff valve 100 in a fully closed position during operation. In this position, downward flowing fluid may bias flowtube 107 belowflapper valve 126 such that the bottom offlow tube 107 may be resting onlower ledge 130. Further,flapper valve 126 may be in the fully closed position. This positioning offlow tube 107 andflapper valve 126 may be caused or assisted by fluid flowing downward throughborehole 118, in a downhole direction. The downward flowing fluid may engage withflexible flaps 152 oforifice disk 146, pushingflexible flaps 152 downward, thereby forcingflow tube 107 to move axially downward until reachinglower ledge 130. As such,flow tube notch 166 may apply a downward force tomovable spring guard 162 thereby axially displacingmovable spring guard 162 in the downward direction and compressingspring 160 betweenmovable spring guard 162 andstationary spring guard 164. Further, the downward flowing fluid may engage with a top side offlapper valve 126, pushingflapper valve 126 intovalve seat 136. Similar to previous embodiments, sealingelement 134 may provide an initial seal forflapper valve 126 until load from the pressure differential of the downward flowing fluid creates a metal-to-metal seal betweenflapper valve 126 andvalve seat 136. In this position, fluid flow withinborehole 118 may be halted, thus preventing any kill fluid from flowing back into the formation, particularly when production has stopped. This may reduce potential reservoir damage due to fluid loss. -
FIGS. 9A and 9B illustrate an alternative embodiment ofshutoff valve 100. In this embodiment,shutoff valve 100 may comprise analternative flow tube 109, which may be similar to that offlow tube 107, but further comprise an orificedisk extension piece 145. In such embodiments,orifice disk 146 may be attached to a bottom opening of orificedisk extension piece 145 viascrews 148, while orificedisk extension piece 145 may in turn be attached to flowtube 109 by any suitable means, such as screws 129. In embodiments,flow tube 109 may function similarly to that offlow tube 107, as is illustrated inFIGS. 9A and 9B .FIG. 9A illustratesalternative shutoff valve 100 in an initial resting position/fully opened position during operation. In this position,spring 160 may bias flowtube 109 such that the top opening may be in contact withupper ledge 120 and aconnection point 171 between orificedisk extension piece 145 and flowtube 109 may be in contact withstationary spring guard 164.Upper ledge 120 andstationary spring guard 164 may provide a means in which to prevent any further upward axial movement offlow tube 109 during operation. Further,flapper valve 126 may be in the fully opened position. Similar to previous embodiments, this positioning offlow tube 109 andflapper valve 126 may be caused or assisted by decompression offlow tube spring 160, which may be capable of applying an upward force throughmovable spring guard 132 to flowtube notch 166, particularly when there may be minimal or no fluid flowing throughborehole 118, or rather when fluid may be flowing upward throughborehole 118, toward the surface of the well. In this position, fluid may continuously flow throughborehole 118, passing throughopening 147 oforifice disk 146, which includes any space created by the displacement offlexible flaps 152, as well as through the flow tube borehole. This may occur with a minimal pressure drop of less than 3 psi. Further in this position,flapper valve 126 may be isolated from the upward flowing fluid, thus preventing any erosion toflapper valve 126 that may otherwise be caused by the upward flowing fluid. -
FIG. 9B illustratesalternative shutoff valve 100 in a fully closed position during operation. In this position, downward flowing fluid may bias flowtube 109 belowflapper valve 126. Further,flapper valve 126 may be in the fully closed position. Similar to previous embodiments, this positioning offlow tube 109 andflapper valve 126 may be caused or assisted by fluid flowing downward throughborehole 118, in a downhole direction. The downward flowing fluid may engage withflexible flaps 152 oforifice disk 146, pushingflexible flaps 152 downward, thereby forcingflow tube 109 to move axially downward until belowclosed flapper valve 126. As such,flow tube notch 166 may apply a downward force tomovable spring guard 162 thereby axially displacingmovable spring guard 162 in the downward direction and compressingspring 160 betweenmovable spring guard 162 andstationary spring guard 164. Further, the downward flowing fluid may engage with a top side offlapper valve 126, pushingflapper valve 126 intovalve seat 136.Sealing element 134 may provide an initial seal forflapper valve 126 until load from the pressure differential of the downward flowing fluid creates a metal-to-metal seal betweenflapper valve 126 andvalve seat 136. In this position, fluid flow withinborehole 118 may be halted, thus preventing any kill fluid from flowing back into the formation, particularly when production has stopped. This may reduce potential reservoir damage due to fluid loss. Although only depicted inFIGS. 9A and 9B thus far, orificedisk extension piece 145 may be implemented on any one of the previous flow tube embodiments. - In addition to
alternative flow tube 109, the alternative embodiment ofshutoff valve 100 illustrated inFIGS. 9A and 9B may further comprise a pump-open sleeve 170. Pump-open sleeve 170 may be a sleeve disposed about an outer surface oftop sub 102 coveringopenings 172, which may lead fromborehole 118 tooutside shutoff valve 100. In embodiments, pump-open sleeve 170 may be attached totop sub 102 via shear screws 176. Further, sealingelements 174 may be disposed radially betweentop sub 102 and pump-open sleeve 170 to aid in sealing offopenings 172. Theseopenings 172 may be disposed throughtop sub 102 in any suitable size, shape, and number, and may provide a means by which to clean out any built-up debris from above a fully closedflapper valve 126. Debris buildup may preventshutoff valve 100 from moving to the fully open position after having been previously closed, thus may inadvertently restrict fluid flow withinborehole 118. -
FIGS. 10A-10G illustrate a progression of debris removal from an embodiment ofshutoff valve 100 comprising pump-open sleeve 170 and experiencing a buildup ofdebris 180.FIG. 10A illustrates an initial state ofshutoff valve 100 experiencing a buildup ofdebris 180 in a fully closed position. In order to removedebris 180, referring now toFIGS. 10B-10D an operator may apply a differential pressure (depicted by arrows 182) toshutoff valve 100 in the downhole direction. This applied differential pressure may be capable actuating pump-open sleeve 170 by shearing shear screws 176, thereby permanently uncoveringopenings 172. By actuating pump-open sleeve 170, at least a portion ofdebris 180 may be displaced frominside borehole 118 throughopenings 172. This displacement ofdebris 180, referring now toFIGS. 10E-10G , may allow at least some fluid flow (depicted by arrows 184) to be restored throughopenings 172. In embodiments, as the at least some fluid flow continues, the removal ofdebris 180 fromabove flapper valve 126 may also continue. Eventually,enough debris 180 may be removed so as to allowshutoff valve 100 to move to the fully open position and thereby allow, once again, upward fluid flow throughborehole 118, as well as throughopenings 172. However, once pump-open sleeve 170 has been actuated,shutoff valve 100 may no longer be capable of moving to the fully closed position. In order to recover this functionality, an operator may need to retrieveshutoff valve 100 and redress the tool. Although only depicted inFIGS. 8A-9G , pump-open sleeve 170 may be implemented on any one of the previous shutoff valve embodiments. - The benefit of the embodiments of
shutoff valve 100 may be that it deals with some common problems in wellbore production. In the absence of a shutoff valve in a producing well, the unobstructed downward flow of fluid may allow the pumping mechanism (e.g., an ESP or gas lift) to move in reverse, which could lead to damage of the pump. This may be especially true if an operator attempts to restart the pump while the pumping mechanism may already be moving in reverse. Another problem may be that unobstructed downward flow of fluid would be permitted to uncontrollably move back into the formation, which could cause serious issues with the productivity of the well. Alternatively, in the absence of a shutoff valve, unwanted upward fluid flow may be allowed to flow freely toward the surface of a well. To avoid this, particularly in injection wells, the embodiments ofshutoff valve 100 may be reciprocally installed, thus capable of preventing unwanted upward fluid flow. Regardless of orientation, the advantages of the embodiments ofshutoff valve 100 may be that it self-operates without the need for control lines or external actuation signals, as well as reduces rig time by maintaining static fluid level created by the downhole barrier. - Although the present invention and its advantages have been described in detail, it should be understood that various changes, substitutions and alterations may be made herein without departing from the spirit and scope of the invention as defined by the appended claims.
Claims (20)
1. A shutoff valve device for permitting and preventing fluid flow in a production string, comprising:
a body comprising a borehole, wherein the body is a top sub coupled to a bottom sub via a threaded fastener;
a flow tube disposed within the body's borehole and capable of axial movement within the body's borehole, comprising a flow tube borehole;
a bi-directional actuator attached to a bottom opening of the flow tube, comprising flexible flaps; and
a flapper valve disposed within the body's borehole, wherein the flapper valve is hingedly coupled to a top surface of the bottom sub and capable of moving between a fully opened and fully closed position.
2. The shutoff valve device of claim 1 , wherein the top sub is further coupled to the bottom sub via shear screws to provide a means in which to shear the top sub from the bottom sub.
3. The shutoff valve device of claim 1 , wherein the bi-directional actuator is made up of rubber material.
4. The shutoff valve device of claim 1 , wherein the flapper valve is positioned in a flapper valve recess when in the fully open position.
5. The shutoff valve device of claim 1 , wherein the flapper valve is positioned to mate with a valve seat when in the fully closed position.
6. The shutoff valve device of claim 1 , wherein the borehole comprises ledges to limit the axial movement of the flow tube.
7. The shutoff valve device of claim 1 , further comprising a pump-open sleeve disposed about an outer surface of the body, and wherein the pump-open sleeve covers openings in the body.
8. The shutoff valve device of claim 7 , wherein the pump-open sleeve is attached to the body via secondary shear screws to provide a means to actuate pump-open sleeve, thereby uncovering the openings.
9. A shutoff valve device for permitting and preventing fluid flow in a production string, comprising:
a body comprising a borehole, wherein the body is a top sub coupled to a bottom sub via a threaded fastener;
a flow tube disposed within the body's borehole and capable of axial movement within the body's borehole, comprising a flow tube borehole;
a compression spring disposed radially between the flow tube and the body, wherein the compression spring biases the flow tube in an axially upward position;
a bi-directional actuator attached to a bottom opening of the flow tube, comprising flexible flaps; and
a flapper valve disposed within the body's borehole, wherein the flapper valve is hingedly coupled to a top surface of the bottom sub and capable of moving between a fully opened and fully closed position.
10. The shutoff valve device of claim 9 , wherein the top sub is further coupled to the bottom sub via shear screws to provide a means in which to shear the top sub from the bottom sub.
11. The shutoff valve device of claim 9 , wherein the bi-directional actuator is made up of rubber material.
12. The shutoff valve device of claim 9 , wherein the flapper valve is positioned in a flapper valve recess when in the fully open position.
13. The shutoff valve device of claim 9 , wherein the flapper valve is positioned to mate with a valve seat when in the fully closed position.
14. The shutoff valve device of claim 9 , wherein the borehole comprises ledges to limit the axial movement of the flow tube.
15. The shutoff valve device of claim 9 , further comprising a pump-open sleeve disposed about an outer surface of the body, and wherein the pump-open sleeve covers openings in the body.
16. The shutoff valve device of claim 15 , wherein the pump-open sleeve is attached to the body via secondary shear screws to provide a means to actuate pump-open sleeve, thereby uncovering the openings.
17. A method for permitting and preventing fluid flow in a production string, comprising:
(A) outfitting a production string with a shutoff valve device comprising:
a body comprising a borehole, wherein the body is a top sub coupled to a bottom sub via a threaded fastener;
a flow tube disposed within the body's borehole and capable of axial movement within the body's borehole, comprising a flow tube borehole;
a bi-directional actuator attached to a bottom opening of the flow tube, comprising flexible flaps; and
a flapper valve disposed within the body's borehole, wherein the flapper valve is hingedly coupled to a top surface of the bottom sub and capable of moving between a fully opened and fully closed position.
18. The method of claim 17 , wherein upward fluid flow through the borehole opens the shutoff valve device by providing an upward force that engages the bi-directional actuator, thereby moving the flow tube axially upward, which in turn opens the flapper valve and permits fluid flow.
19. The method of claim 17 , wherein downward fluid flow through the borehole closes the shutoff valve device by providing a downward force that engages the bi-directional actuator, thereby moving the flow tube axially downward, which in turn allows the flapper valve the ability to be closed by the downward force and prevent fluid flow.
20. The method of claim 17 , wherein the bi-directional actuator is made up of rubber material.
Priority Applications (1)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
US17/403,705 US20220049575A1 (en) | 2020-08-14 | 2021-08-16 | Shutoff Valve |
Applications Claiming Priority (2)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
US202063065864P | 2020-08-14 | 2020-08-14 | |
US17/403,705 US20220049575A1 (en) | 2020-08-14 | 2021-08-16 | Shutoff Valve |
Publications (1)
Publication Number | Publication Date |
---|---|
US20220049575A1 true US20220049575A1 (en) | 2022-02-17 |
Family
ID=80224081
Family Applications (1)
Application Number | Title | Priority Date | Filing Date |
---|---|---|---|
US17/403,705 Abandoned US20220049575A1 (en) | 2020-08-14 | 2021-08-16 | Shutoff Valve |
Country Status (1)
Country | Link |
---|---|
US (1) | US20220049575A1 (en) |
Cited By (1)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US11852003B2 (en) | 2021-08-10 | 2023-12-26 | Daniel J. Snyder | Sand collector for sucker rod pump |
Citations (6)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US4834176A (en) * | 1988-04-11 | 1989-05-30 | Otis Engineering Corporation | Well valve |
US5577857A (en) * | 1993-12-27 | 1996-11-26 | Daido Concrete Co., Ltd. | Joint structure for pillars and its joining method |
US20070095542A1 (en) * | 2005-10-31 | 2007-05-03 | Lembcke Jeffrey J | Injection valve |
US20110030968A1 (en) * | 2009-08-10 | 2011-02-10 | Baker Hughes Incorporated | Tubular actuator, system and method |
US20140069627A1 (en) * | 2012-09-12 | 2014-03-13 | Halliburton Energy Services, Inc. | Resilient Downhole Flow Restrictor |
US20150000982A1 (en) * | 2013-06-26 | 2015-01-01 | Weatherford/Lamb, Inc. | Bidirectional downhole isolation valve |
-
2021
- 2021-08-16 US US17/403,705 patent/US20220049575A1/en not_active Abandoned
Patent Citations (6)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US4834176A (en) * | 1988-04-11 | 1989-05-30 | Otis Engineering Corporation | Well valve |
US5577857A (en) * | 1993-12-27 | 1996-11-26 | Daido Concrete Co., Ltd. | Joint structure for pillars and its joining method |
US20070095542A1 (en) * | 2005-10-31 | 2007-05-03 | Lembcke Jeffrey J | Injection valve |
US20110030968A1 (en) * | 2009-08-10 | 2011-02-10 | Baker Hughes Incorporated | Tubular actuator, system and method |
US20140069627A1 (en) * | 2012-09-12 | 2014-03-13 | Halliburton Energy Services, Inc. | Resilient Downhole Flow Restrictor |
US20150000982A1 (en) * | 2013-06-26 | 2015-01-01 | Weatherford/Lamb, Inc. | Bidirectional downhole isolation valve |
Cited By (1)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US11852003B2 (en) | 2021-08-10 | 2023-12-26 | Daniel J. Snyder | Sand collector for sucker rod pump |
Similar Documents
Publication | Publication Date | Title |
---|---|---|
US6296061B1 (en) | Pilot-operated pressure-equalizing mechanism for subsurface valve | |
US7543651B2 (en) | Non-elastomer cement through tubing retrievable safety valve | |
AU2011330955B2 (en) | Valve assembly | |
US20070119598A1 (en) | System and method for downhole operation using pressure activated and sleeve valve assembly | |
CA2710008C (en) | Full bore injection valve | |
CA2496331C (en) | Seal assembly for a safety valve | |
WO2011005826A1 (en) | Surface controlled subsurface safety valve assembly with primary and secondary valves | |
US7938189B2 (en) | Pressure protection for a control chamber of a well tool | |
US20210172278A1 (en) | Jettisonable ball seal | |
US10900326B2 (en) | Back flow restriction system and methodology for injection well | |
US7178599B2 (en) | Subsurface safety valve | |
US20220049575A1 (en) | Shutoff Valve | |
US6427773B1 (en) | Flow through bypass tubing plug | |
US20200088000A1 (en) | Automatically Resetting Tubing String Bypass Valve | |
US11203917B2 (en) | Equalizing device for safety valves | |
US20140069654A1 (en) | Downhole Tool Incorporating Flapper Assembly | |
US11041365B2 (en) | Annular controlled safety valve system and method | |
US20180187514A1 (en) | Metal to metal single ball seat system | |
US9051809B2 (en) | Casing relief valve | |
US10337286B1 (en) | Resealable tubing drain for oilfield service | |
US9784069B1 (en) | Hydraulic drain for oilfield service | |
US11697977B2 (en) | Isolation valve for use in a wellbore | |
US20220251917A1 (en) | Annular fracturing cleanout apparatus and method | |
US20230003100A1 (en) | A valve assembly | |
GB2616431A (en) | Apparatus |
Legal Events
Date | Code | Title | Description |
---|---|---|---|
STPP | Information on status: patent application and granting procedure in general |
Free format text: DOCKETED NEW CASE - READY FOR EXAMINATION |
|
STPP | Information on status: patent application and granting procedure in general |
Free format text: FINAL REJECTION MAILED |
|
STCB | Information on status: application discontinuation |
Free format text: ABANDONED -- FAILURE TO RESPOND TO AN OFFICE ACTION |