SELECTIVE ISOLATION OF SURFACE CONTROLLED GAS LIFT VALVE

Description

CROSS-REFERENCE TO RELATED APPLICATION

This application claims priority to and the benefit of co-pending U.S. Provisional Application Ser. No. 63/705,335, filed Oct. 9, 2024, and co-pending U.S. patent application Ser. No. 18/664,087, filed May 14, 2024, the full disclosures of which are incorporated by reference herein in their entireties and for all purposes.

BACKGROUND OF THE INVENTION

1. Field of Invention

The present disclosure relates to selectively isolating a surface controlled gas lift valve.

2. Description of Prior Art

A gas lift system is a type of artificial lift sometimes used for assisting with the production of liquid from inside a wellbore. When the liquid being lifted is in production tubing installed in the wellbore, the lift gas is usually directed into an annulus between the production tubing and sidewalls of the well, and then routed into the production tubing through a gas lift valve. Conversely, when the liquid is in the annulus, the lift gas is injected into the tubing, and through the gas lift valve into the annulus. Gas lift is commonly employed when pressure in a formation surrounding the well is insufficient to urge fluids to surface that are inside of the production tubing. By injecting sufficient lift gas into the production tubing, static head pressure of fluid inside the production tubing is reduced to below the pressure in the formation, so that the formation pressure is sufficient to push the fluids inside the production tubing to surface. Fluids that are usually in the production tubing are hydrocarbon liquids and gases produced from the surrounding formation.

The lift gas is typically transported to the well through a piping circuit on surface that connects a source of the lift gas to a wellhead assembly mounted over the well. Usually, valves are mounted on the production tubing for regulating the flow of lift gas into the production tubing from the annulus. Some types of these valves automatically open and close in response to designated pressures in the annulus and/or tubing, while other valve types are motor operated and controlled by signals delivered from surface or another remote location. Gas lift valves are usually mounted to production tubing, corrective action to address a gas lift valve malfunction therefore often requires removal of the production tubing, which is costly and time consuming. In some well completions cement is injected through the tubing in the upper completion instead of a temporary work string as a cost savings measure. A problem with cementing through an upper completion is that when the cement hardens, some components are susceptible to damage from plugging or being locked in place.

SUMMARY OF THE INVENTION

Disclosed is an example of a method of wellbore operations that includes producing fluid from a wellbore through production tubing that is disposed in the wellbore, injecting lift gas into the production tubing through a port formed on a sidewall of the production tubing, adding a substance into the production tubing that is present in the production tubing for a designated period of time, and shielding the port from the substance for at least the designated period of time. The step of shielding optionally includes forming a barrier with a material that remains cohesive for the designated period of time and dissolves after the designated period of time. In another alternative, shielding includes forming a barrier with an insert having a pressure actuated valve, and actuating the valve after the designated period of time by adjusting pressure inside the production tubing. In one example, the step of adding occurs during an operation such as, cementing, acidizing, or chemical injection. In an example, the lift gas is injected into the production tubing through a surface controlled flow control valve (“SCFCV”) that is attached to the production tubing, which in an alternative is susceptible to damage when exposed to the substance. In one embodiment, the material is configured into a plug and retained inside the production tubing adjacent the port In an example, the substance includes a first substance, the method of this example includes injecting a second substance into the production tubing after the designated period of time. In an alternative, the method further includes injecting lift gas into the production tubing after the designated period of time. In an alternative, the port is located in a side pocket mandrel of the production tubing, optionally, the side pocket mandrel is formed in an enlarged diameter portion of the production tubing, the side pocket mandrel in this alternative is made up of a planar skirt that extends axially inside the production tubing with lateral edges attached to inner sidewalls of the production tubing to form a cylinder, where upper and lower ends of the cylinder are open to a bore in the production tubing. In further alternatives, the material is formed into a plug and installed in the cylinder at a location in a flow path between a side port formed through the skirt and the inlet port, and optionally an insert is disposed above the plug, and where the insert is moveable into the flow path.

Another example method of wellbore operations is disclosed that includes flowing a produced fluid in a bore of a tubular disposed in a wellbore, injecting a secondary fluid into the tubular that mixes with the produced fluid, controlling injection of the secondary fluid with a valve that is coupled to the tubular, introducing a substance into the tubular that is in the tubular for a designated period of time, and shielding the valve from the substance for at least the designated period of time. The step of shielding alternatively includes forming a barrier to communication of the substance with the valve by adding a material between the bore and the valve, where the material remains cohesive for the designated period of time, and after the designated period of time, the material degrades into a non-cohesive state to remove the barrier. In an embodiment, the tubular is made up of production tubing having a side pocket mandrel, where the valve is in communication with the bore through a port formed through a sidewall of the side pocket mandrel, and where the material is formed into a plug that is inserted into a cylinder formed in the side pocket mandrel. Alternatively, the substance is a wellbore cement that is injected into the bore on surface, and the method further includes purging the cement from the bore and repeating the steps of flowing and injecting.

A system for use in wellbore operations is disclosed that includes a wellhead assembly mounted over a wellbore, a tubular in the wellbore in communication with the wellhead assembly, a valve coupled with the tubular, a flow path between a bore in the tubular and the valve, and a plug in the flow path made with a material that over time changes from being cohesive and forming a barrier to fluid communication along the flow path to a degraded state and allows fluid communication along the flow path. In an example, the tubular is production tubing, the valve is a surface controlled flow control valve that is configured to control flow from an annulus formed around the production tubing to the bore, and the plug is disposed in a cylinder formed in a side pocket mandrel of the production tubing. In one embodiment, the cylinder extends axially in the side pocket mandrel and has sidewalls radially intersected by a side port and an inlet port, the cylinder is in selective communication with the bore through the side port, and is in selective communication with an exit of the valve through the inlet port, and the plug is a barrier to flow between the side port and the inlet port.

BRIEF DESCRIPTION OF DRAWINGS

Some of the features and benefits of the present invention having been stated, others will become apparent as the description proceeds when taken in conjunction with the accompanying drawings, in which:

FIG. 1A is a side partial sectional view of an example of a well having a surface controlled gas lift valve.

FIG. 1B is a side partial sectional view of an example of conducting a contingency operation on the surface controlled gas lift valve of FIG. 1A.

FIG. 2 is a side sectional view of an example of the surface controlled gas lift valve of FIG. 1A in a side pocket mandrel and injecting lift gas into production tubing.

FIG. 3 is a side sectional view of an example of the surface controlled gas lift valve of FIG. 2 out of service.

FIG. 4A is a side sectional view of an example of a contingency insert for use when the surface controlled gas lift valve of FIG. 2 is out of service.

FIGS. 4B-4D are side sectional views of an example of installing the contingency insert of FIG. 4A into the side pocket mandrel of FIG. 2.

FIG. 4E is a side sectional view of an example of operation of the contingency insert of FIG. 4A.

FIG. 5A is an elevational sectional view of the surface controlled gas lift valve installed in an alternate embodiment of a side pocket mandrel.

FIG. 5B is an axial sectional view of the side pocket mandrel of FIG. 5A and taken along lines 5B-5B.

FIG. 5C is an elevational sectional view of a portion of the side pocket mandrel of FIG. 5B and taken along lines 5C-5C.

FIGS. 5D-5G are side sectional views of example embodiments of inserts for use in the side pocket mandrel of FIG. 5A.

FIG. 6A is a side sectional view of an example of a side pocket mandrel having a barrier for blocking fluid communication.

FIG. 6B is a side sectional view of an example of the side pocket mandrel of FIG. 6A with the barrier removed.

FIG. 6C is a side sectional view of an alternate example of the side pocket mandrel of FIG. 6A.

FIG. 7A is a side sectional view of an example of a side pocket mandrel with a means for selectively blocking fluid communication and shown in a closed configuration.

FIG. 7B is a side sectional view of the side pocket mandrel of FIG. 7A with the blocking means shown in an open configuration.

While subject matter is described in connection with embodiments disclosed herein, it will be understood that the scope of the present disclosure is not limited to any particular embodiment. On the contrary, it is intended to cover all alternatives, modifications, and equivalents thereof.

DETAILED DESCRIPTION OF INVENTION

The method and system of the present disclosure will now be described more fully hereinafter with reference to the accompanying drawings in which embodiments are shown. The method and system of the present disclosure may be in many different forms and should not be construed as limited to the illustrated embodiments set forth herein; rather, these embodiments are provided so that this disclosure will be thorough and complete, and will fully convey its scope to those skilled in the art. Like numbers refer to like elements throughout. In an embodiment, usage of the term “about” includes +/−5% of a cited magnitude. In an embodiment, the term “substantially” includes +/−5% of a cited magnitude, comparison, or description. In an embodiment, usage of the term “generally” includes +/−10% of a cited magnitude.

It is to be further understood that the scope of the present disclosure is not limited to the exact details of construction, operation, exact materials, or embodiments shown and described, as modifications and equivalents will be apparent to one skilled in the art. In the drawings and specification, there have been disclosed illustrative embodiments and, although specific terms are employed, they are used in a generic and descriptive sense only and not for the purpose of limitation.

Shown in a side sectional view in FIG. 1 is an example of a well system 10, which includes a string of production tubing 12 installed within a wellbore 14 that intersects a subterranean formation 16. The wellbore 14 is lined with casing 18 that has a number of perforations 20 shown projecting radially outward from the wellbore 14 into the surrounding formation 16. In this example, the perforations 20 provide a pathway for fluid F to flow into the wellbore 14 from the formation 16. In the example shown the fluid F is made up primarily of liquid with some small bubbles of gas G mixed within. A packer 22 circumscribes a downhole end of tubing 12 to block the fluid F from flowing into an annulus 24 between the tubing 12 and casing 18. The fluid F instead flows into a bore 25 in the production tubing 12.

The well system 10 includes a lift gas system 26 for assisting the flow of the fluid F uphole within the bore 25 of production tubing 12. In the example of FIG. 1, the lift gas system 26 includes a lift gas source 28 shown on the surface, embodiments of lift gas source 28 include an adjacent well, a pipeline, or a vessel. Lift gas source 28 provides lift gas 30, which is shown being injected into the annulus 24 through an injection line 32. Lift gas 30 inside injection line 32 is at a designated pressure so that the lift gas 30 is forced downhole within annulus 24 to a surface controlled gas lift valve (“SCGLV”) 34 shown mounted on an outer surface of the production tubing 12. SCGLV 34 is intermittently opened to allow the lift gas 30 into the bore 25 of production tubing 12, once in the bore 25, bubbles 35 of lift gas 30 are formed inside the fluid F. In alternatives, fluid F is referred to as a produced fluid and the lift gas 30 is referred to as a secondary fluid. The lower density bubbles 35 reduce the density of the fluid F to assist the flow of fluid F uphole inside bore 25 and to a wellhead assembly 36 shown mounted over the wellbore 14 and connected to an end of production tubing 12. Inside wellhead assembly 36, the fluid F is directed to a production line 38 shown attached to a lateral side of wellhead assembly 36. Inside production line 38, fluid F is carried to a location that is offsite for transportation or to a processing facility (not shown). In the example of FIG. 1A, a controller 40 is schematically illustrated outside of wellbore 14 and in signal communication with the SCGLV 34 via communication means 42. Examples of communication means 42 include electrically conducting wire, fiber optics, hydraulics, and wireless, such as telemetry. Further optionally included are sensors 44 that are in temperature and pressure communication with annulus 24 and/or bore 25, and which transmit downhole conditions to controller 40 via communication means 42.

Shown in a side sectional view in FIG. 2 is an example of the production tubing 12 with the SCGLV 34 connected to a side pocket mandrel 46 of the production tubing 12; which is an enlarged diameter portion of tubing 12. Axial ends of the side pocket mandrel 46 extend obliquely from an outer surface of tubing 12 and are angled towards one another. In the example shown, SCGLV 34 connects to a downhole end of the side pocket mandrel 46. Inside the side pocket mandrel 46 is a skirt 48 shown extending along a path that is generally parallel with an axis A₁₂ of production tubing 12, a downhole end of skirt 48 attaches to the downhole end of side pocket mandrel 46, and an uphole end of skirt 48 is proximate a mid-portion of side pocket mandrel 46. Lateral edges of skirt 48 attach to inner sidewalls of side pocket mandrel 46 at angularly spaced apart locations. A cylinder 50 is defined between skirt 48 and inner sidewalls of the side pocket mandrel 46. An inlet port 52 is formed through the downhole end of side pocket mandrel 46, a nipple 53 connects port 52 to an outlet of SCGLV 34, which provides communication between SCGLV 34 and cylinder 50. A side port 54 is formed radially through the skirt 28, and which provides a pathway of lift gas 30 within the cylinder 50 to flow into the bore 25.

In the side pocket mandrel 46 of FIG. 2, a contingency port 56 is formed radially through an outer side wall of side pocket mandrel 46, which as described in more detail below, provides an inlet for a contingency flow of lift gas 30 when and if the SCGLV 34 is a non-operational state. An example of the SCGLV 34 being in a non-operational state is that the SCGLV 34 is remains in a fully open/closed or partially open/closed configuration, and is not responsive to command signals, such as from surface via communication means 42. Another example of a non-operational state of SCGLV 34 is a blockage 57 in port 52 or nipple 53 that forms a barrier to fluid flow therethrough. In a non-limiting example of operation during which SCGLV 34 is in an operational state, communication from annulus 24 to inside of cylinder 50 through the port 56 is blocked by an insert 58 shown installed within the cylinder 50. An example of SCGLV 34 being in an operational state, is that the SCGLV 34 is selectively opened and closed in response to command signals from surface transmitted via communication means 42 (FIG. 1A) to inject lift gas 30 into bore 25. In the example of FIG. 2, insert 58 is elongated and substantially solid. O-ring seals 60, 62 are shown circumscribing the insert 58 at spaced apart locations, and which respectively form barriers to fluid flow from contingency port 56 to side port 54 and an opening of cylinder 50.

Shown in a side sectional view in FIG. 3 is an example in which the SCGLV 34 of FIG. 2 is in a non-operational state, and a blind insert 64 is disposed in cylinder 50 in an example attempt to block lift gas 30 in the annulus 24 from reaching the bore 25 through the SCGLV 34 or ports 54, 56 in the side pocket mandrel 46. In this example, the blind insert 64 is inserted into the cylinder 50 after the insert 58 (FIG. 2) has been removed from within cylinder 50. A problem encountered is that the presence of fluid F, which is not fully compressible, remains within cylinder 50 and so that blind insert 64 is prevented from being inserted within cylinder 50 to a location such that an O-ring seal 66 circumscribing insert 64 remains adjacent side port 54, and cannot isolate inlet 54 from SCGLV 34.

Shown in a side sectional view in FIG. 4A is an example of a contingency insert 68 equipped to compensate for the incompressible fluid problem illustrated in FIG. 3. Contingency insert 68 includes a body 70 having an uphole end 72 profiled similar to what is commonly known as a fishing neck. Adjacent the uphole end 72 is a recess along an outer surface of body 70 and in which a spring 74 is installed, spring 74 is part of a latching mechanism for retrieving the insert 68. A chamber 76 is formed within a mid-portion of body 70, chamber 76 has an outer diameter that transitions radially inward to form an uphole-facing shoulder 78, the outer diameter transitions radially outward a distance away from shoulder 78 to form a downhole-facing shoulder 80. A valve member 82 is shown in chamber 76 having a downhole end that is rounded and in contact with shoulder 78, an uphole end of valve member 82 is generally planar and shown attached to a downhole end of bellows 84. An uphole end of bellows 84 is mounted to an uphole end of chamber 76. Another valve member 86 is inside chamber 76 shown abutting shoulder 80. Valve member 86 is shown as a generally spherical member and biased against shoulder 80 by a spring 88, an end of spring 88 opposite valve member 86 abuts an end wall 90, which defines a downhole end of chamber 76. In the example shown, chamber 76 is isolated from the surrounding environment by the bellows 84. An inlet port 92 is formed radially into the body 70, which extends into chamber 76 and adjacent a lateral surface of valve member 82. An exit port 94 extends radially into body 70 and intersects chamber 76 at a location adjacent valve member 86. The combination of the valve members 82, 86, ports 92, 94, chamber 76, and bellows 84 is configured to operate substantially the same as an injection pressure operated (“IPO”) valve. An example of an IPO valve is found in Shaw, U.S. Pat. No. 11,441,401, which is assigned to the assignee of the present application and incorporated by reference herein in its entirety and for all purposes. A receptacle 96 is shown formed into an end of body 70 opposite from uphole end 72, in the example shown receptacle 96 is a generally cylindrical void having an uphole end that is spaced away location downhole of end wall 90. A bleed plug 98 is shown having a shaft 100 that inserts into the receptacle 96. Bleed plug 98 includes a nose portion 102 shown with an outer diameter exceeding shaft 100, nose portion 102 attaches to an end of shaft 100 outside of receptacle 96. A passage 104 extends axially through the bleed plug 98 and along a path substantially parallel with axis A₆₈ of insert 68. Inside shaft 100 are ducts 106 that project radially outward from passage 104, in the example of FIG. 4A ducts 106 are registered with bleed ports 107 that extend radially from the receptacle 96 to an outer surface of body 70. An O-ring 108 circumscribes an outer surface of the nose portion 102, and O-rings 110, 112 circumscribe shaft 100 on opposing sides of the ducts 106. O-rings 114 are also shown circumscribing body 70 at an axial location between shoulders 78, 80.

Shown in FIGS. 4B and 4C is insertion of the contingency insert 68 into the cylinder 50 and how the fluid within cylinder 50 is vented through the bleed plug 98, which allows for insertion of the contingency insert 68 to a designated location within the cylinder 50. More specifically, in FIG. 4B the nose plug 98 is shown having been inserted to a bottom portion of cylinder 50, and the fluid pooled in the bottom portion of cylinder 50 being ported into the passage 104 and exiting into the bleed port 107 via the ducts 106, and where it escapes from the cylinder 50 through the side port 54. Referring back to FIG. 4A, shown is a shear pin 116 that extends radially through shaft 100 and body 70, and which retains shaft 100 in a fixed location and so that ducts 106 and port 107 remain in registration with one another. A retaining pin 118 projects radially through the side wall of body 70 and into a recess 120 that extends axially along an outer surface of shaft 100. The retaining pin 118 limits axial reciprocating motion of shaft 100 within the receptacle 96.

Referring now to FIG. 4C, further axial urging of the insert 68 into the cylinder 50 fractures shear pin 116 allowing relative movement between the bleed plug 98 and body 70, which moves the port 106 and duct 107 out of registration with one another. As illustrated in FIG. 4D, continued axial urging of the insert 68 into the cylinder 50 urges bleed plug 98 deeper into receptacle 96 and further compressing a spring 122 shown within receptacle 96 and abutting an end of shaft 100 opposite the nose portion 102. The combination of the O-ring seals 108, 114, 110 and 112 and the non-registration of ports and ducts 106, 107 block fluid communication between port 52 and bore 25. Though a path P for lift gas 30 within annulus 24 to be selectively injected into bore 25 is shown in FIG. 4E. In the example of FIG. 4E, the contingency insert 68 operates as an IPO valve, and the lift gas 30 within annulus 24 enters port 56 due to a pressure differential between annulus 24 and bore 25. The path P extends through port 56, across the interfaces between valve elements 82, 86 and shoulders 78, 80, between body 70 and skirt 48, and through port 54 into bore 25. In an alternate embodiment, contingency insert operates as a production pressure valve and responsive to pressure inside the bore 25.

Shown in FIGS. 5A-5C is an alternate example of a side pocket mandrel 46A formed on a portion of production tubing 12A. In this example, the inlet port 52A, which is in communication with the SCGLV 34A, is formed through a side wall of the side pocket mandrel 46A and spaced away from its downhole end. Further, the skirt 48A is also spaced away from the downhole end of the side pocket mandrel 46A, and so that fluid cannot collect to hinder full insertion of insert 58A into cylinder 50A as discussed above in FIG. 3. Insert 58A blocks flow communication between ports 54A, 56A. Shown in an axial sectional view in FIG. 5B, and taken along the lines 5B-5B of FIG. 5A, is that the side pocket mandrel 46A includes a lead port 124A (which similar to the inlet port 52 of FIG. 2) that provides an inlet for lift gas from the SCGLV 34A to make its way into cylinder 50A through port 52A and then into the bore 25A of production tubing 12A. Lead port 124A extends generally axially within a manifold 126A formed in the side pocket mandrel 46A. And shown in FIG. 5C, which is taken along lines 5C-5C of FIG. 5B, is that inlet port 52A provides communication from lead port 124A and into cylinder 50A, where lift gas is communicated through cylinder 50A into the bore 25A of production tubing 12A.

In FIGS. 5D-5G are alternate examples of inserts for installation in cylinder 50A of FIGS. 5A-5C. In the example of FIG. 5D an outer sleeve 128D is provided on a downhole end of the insert 58D, which in alternatives is formed from a material that will not degrade, or degrade to a lesser degree when particles or other abrasive material is suspended within the lift gas. In FIG. 5E is another embodiment of an insert 58E which is dimensioned to fit within cylinder 50A and having strategically located O-ring seals on its outer surface to provide selective isolation to prevent any leakage or flow that may occur through a SCGLV 34A being in a non-operational state. Shown in a side sectional view in FIG. 5F is an alternate embodiment of an insert 58F shown having valve members 82F, 86F, shoulders 78F, 80F, chamber 76F, inlet port 92F, exit port 94F, and to provide operation similar to the IPO valve discussed above with regard to FIG. 4B and FIG. 4E. In another alternative, shown in a side sectional view in FIG. 5G, is an example of an insert 58G which includes a side port 130G formed in its body 70G that intersects chamber 76G within body 70G, within chamber 76G is a valve element 86G that in this example is largely spherical, and a spring 88G is provided to bias valve element 86G into abutting contact with shoulders 78G. The valve element 86G and spring 88G in combination with ports 92G, 94G operate similar to a check valve to allow for lift gas flow through the insert 58G.

Referring now to FIG. 1B, shown is an example of operation in which the SCGLV 34 is in a non-operational state, and unable to inject lift gas 30 from the annulus 24 into the production tubing 12. In an embodiment, the non-operational state of the SCGLV 34 is detected by monitoring output signals from the sensors 44 or other sensors (not shown), or diagnostic software within controller 40. To remediate the non-operational state of the SCGLV 34, insert 58 (FIG. 2) is replaced with a contingency insert, such as contingency insert 68 of FIG. 4A. In this example, a kickover tool 132 is shown deployed within the production tubing 12 and suspended on a line 134. An optional lubricator 136 is mounted on an upper end of wellhead assembly 36, which provides pressure control for the line 134. Examples of the line 134 include wireline, slickline, coiled tubing, braided wire, and any other means for deploying a device within a well. A deployment means 138 is schematically shown attached to an end of line opposite kickover tool 132; examples of deployment means 138 include an injector, such as when dealing with coiled tubing, or a winch of when dealing with wireline or slickline. Further in the example, the kickover tool 132 is shown deployed at a depth adjacent to the side pocket mandrel 46 and for handling of the insert 58 and contingency insert 68. After installation of the contingency insert 68, lift gas 30 is selectively injected into the bore 25 by pressurizing lift gas 30 in annulus 24, which as shown in FIG. 4E, injects lift gas 30 into bore 25 and forms bubbles 35 of lift gas 30.

Shown in a side sectional view in FIG. 6A is an example of production tubing 12H having a flow of a substance 140H that is potentially damaging to the SCGLV 34H. Examples of substance 140H include wellbore cement, corrosive fluid, or a fluid with entrained particles, such as proppant, fracturing remnants, or any debris, which is capable of blocking flow through ports or cylinders or interfere with actuation of SCGLV 34H. Included with production tubing 12H is a side pocket mandrel 46H having an insert 58H disposed within the cylinder 50H of the side pocket mandrel 46H. In the example of FIG. 6A, communication from annulus 24H into cylinder 50H is blocked by insert 58H that spans across contingency port 56H and has seals shown circumscribing its outer circumference, which block seepage past the insert 58H. As shown, insert 58H is spaced axially away from side port 54H₁, and does not impede communication from annulus 25H into cylinder 50H. A plug 150H is shown in cylinder 50H between insert 58H and SCGLV 34H. A portion of plug 150H spans across side port 54H₁, and is exposed to fluid in bore 25H through the port 54H₁. Plug 150H is circumscribed by seals that are in sealing contact with an inner surface of the cylinder 50H. Plug 150H and its seals form a barrier to fluid communication between bore 25H and cylinder 50H across side port 54H₂. When plug 150H is intact in cylinder 50H as shown in FIG. 6A, SCGLV 34H is isolated from substance 140H, or other fluids, flowing inside production tubing 12H.

In an example, the plug 150H is formed from a material that is initially cohesive enough to operate as a barrier to fluid flow between ports 52H, 54H₂, but after a designated period of time, the the plug 150H degrades and is no longer cohesive enough to block fluid communication between ports 52H, 54H₂. The plug 150H eventually dissolves, and as seen in FIG. 6B, plug 150H has disintegrated and is no longer a barrier between the bore 25H and inlet port 52H to SCGLV 34H. In examples, the plug 150H remains cohesive while substance 140H is in or flowing within a location of tubing 12H proximate ports 54H_{1, 2} and shields SCGLV 34H from substance 140H. Further in this example, plug 105H remains cohesive and does not dissolve until substance 140H is no longer inside the production tubing 12H (flowing or otherwise) proximate ports 54H_{1, 2} or at a location where substance 140H could possibly contact SCGLV 34H. It is within the capabilities of one skilled to select a material that dissolves over time to change to a degraded state, during the designated period of time and before dissolving, the material retains sufficient integrity to form a flow barrier between ports 52H, 54H₁ while substance 140H is inside bore 25H. Examples of material used in forming the plug 150H include magnesium, magnesium based, metal, metal based polyglycolic, polyglycolic based thermoplastic, thermoplastic based, and combinations. Also shown in FIG. 6B is another substance 151H flowing within bore 25H, which is not potentially damaging to the SCGLV 34H, and that is introduced into the bore 25H after substance 140H is no longer within bore 25H.

Still referring to FIGS. 6A and 6B, in a non-limiting example of operation, plug 150H is in place, while directed downhole inside bore 25H is a fluid that is potentially damaging to the SCGLV 34H. Examples of such operations include cementing, acidizing, chemical injection, and the like. As noted above, the plug 150H remains cohesive and operates as a barrier between ports 52H, 54H₁ while these operations are undertaken and fluids potentially damaging to the SCGLV 34H are in the bore 25H. The plug 150H then degrades. Another substance 151H is introduced into bore 25H, and without a cohesive plug 150H in the cylinder 50H, substance 151H to allowed to communicate between the SCGLV 34H and bore 25H along the flow path that extends across the side pocket mandrel 46, port 52H, and nipple 53H. In alternatives, the plug 150H degrades before or after the another substance 151H is introduced into bore 25H. In examples, the material making up plug 150H is responsive to substance 140H, and degrades from exposure to substance 140H. Optionally, plug 150H is responsive to the another substance 151H, and yet further optionally, plug 150H is response to a third substance (not shown), which is injected into production tubing 12H between when substances 140H, 151H are flowing in tubing 12H. An alternative embodiment is shown in a side sectional view in FIG. 6C in which another plug 152H is in cylinder 50H on a side of insert 58H opposite plug 150H. In this example, plug 152H includes a material that degrades over time in response to a potentially damaging substance that flows inside the production tubing 12. In an example of use, plug 152H occupies space uphole of insert 58H and remains cohesive for a designated period of time during which substance 140H is present in the bore 25H and adjacent side pocket mandrel 46H. Which blocks substance 140H from entering that space, so that after the designated period of time no amount of substance 140H will have remained and/or hardened in space to maintain clear and open access to insert 58H.

Shown in a side sectional view in FIG. 7A is another example of an insert 58I configured to selectively isolate a SCGLV 34I from communication with a substance 140I in bore 25I of production tubing 12I, which is potentially damaging to the SCGLV 34I. In this example, inside insert 58I is a chamber 76I and a side port 154I. Chamber 76I extends axially from a lower end of insert 58I and terminates proximate uphole end 721. The side port 154I projects radially between chamber 76I and a lateral outer surface of insert 58I, an outlet of side port 154I registers with contingency port 56I. Another side port 156I distal from uphole end 721 extends radially from chamber 76I to the outer surface of insert 58I and that registers with side port 5412. Inside chamber is a valve assembly 158I that includes an elongated base 160I, a shaft 1621 attached to an end of base 160I opposite uphole end 721, and a cylindrical valve member 163I on an end of shaft 1621 opposite its attachment to base 160I. In FIG. 7A the valve assembly 158I is in a closed configuration. The interface between the inner surface of chamber 76I and base 160I includes a seal 164I, such as an O-ring, that blocks pressure communication axially along the interface; as such, pressure in the portion of chamber 76I past the seal is isolated from pressure in annulus 24I. Similarly, another seal 165I, such as an O-ring, circumscribes valve member 163I and forms a sealing interface between the inner surface of chamber 76I and valve member 163I. Seal 165I blocks fluid communication between side port 156I and inlet 52I through chamber 76I, and in the example shown is a barrier to a flow of substance 141I to SCGLV 34I. An annular recess 166I is included in the example of FIG. 7A and formed in the sidewalls of chamber 76I circumscribing base 160I adjacent side port 154I. A lock ring 1681 is disposed in recess 166I, lock ring 1681 is pretensioned to compress radially inward against the outer surface of base 160I. The example of FIG. 7A also includes a shear pin 170I shown extending radially through sidewalls of insert 58I and intersecting the base 160I, shear pin 170I axially retains valve assembly 158I in the chamber 76I.

Referring now to FIG. 7B, valve assembly 158I is in an open configuration, illustrating that insert 58I is configured to selectively allow communication between bore 25I and port 52I. In a non-limiting example of operation, the valve assembly 158I is reconfigured from the closed configuration of FIG. 7A to the open configuration of FIG. 7B by pressurizing the annulus 24I. In an alternative, the valve assembly 158I is reconfigured from closed to open when substance 140I is not in bore 25H, to change valve assembly 158I from the closed configuration to the open configuration. Examples of pressurization include the introduction of pressurized gas (including natural gas) or other fluids injected from surface. Increasing pressure in annulus 24I to a designated magnitude above that of bore 25I exerts an axial force onto an uphole side of base 160I exceeding the yield strength of the material making up the shear pin 170I and causing it to fracture. After the shear pin 170I is fractured, continued pressurization of annulus 24I urges valve assembly 158I axially within chamber 76I away from upper end 721 until valve member 163I lands against a lower terminal end of insert 58I and outside chamber 76I. The port 156I and valve member 163I are strategically dimensioned so that when the valve member 163I lands against the lower terminal end of insert 58I, the seal 165I outside of chamber 76I. The diameter of chamber 76I exceeds that of shaft 1621 to form an annulus that allows fluid communication axially through the chamber 76I. So that when valve member 163I is outside of chamber 76I, fluid communication is permitted between side ports 5412, 156I to port 52I via chamber 76I. As ports 54I₂, 156I are open to bore 25I and port 52I is open to SCGLV 34I, urging valve member 163I outside of chamber 76I allows for fluid communication between bore 25I to SCGLV 34I. In examples when inserts 58H, 58I are in the open configuration, SCGLV 34H, 34I are activated to permit fluid communication of lift gas in annulus 24H, 24I into bore 25H, 25I.

The present invention described herein, therefore, is well adapted to carry out the objects and attain the ends and advantages mentioned, as well as others inherent therein. While a presently preferred embodiment of the invention has been given for purposes of disclosure, numerous changes exist in the details of procedures for accomplishing the desired results. For example, embodiments exist in which inserts that are the same or similar to inserts 58H, 58I of FIGS. 6A, 6B, 7A, and 7B are used to protect a surface controlled valve are inserted into a cavity (not shown) that is not part of a side pocket mandrel. In an alternative, inserts 58H, 58I are not wireline retrievable, optionally, are not limited to use with surface controlled gas lift valves, and further optionally, are used in combination with any type of downhole flow valve, such as but not limited to an inflow control valve.

Embodiments of the surface controlled flow valves include other types of flow control valves for controlling flow in a wellbore, such as inflow control valves and/or circulation valves. These and other similar modifications will readily suggest themselves to those skilled in the art, and are intended to be encompassed within the spirit of the present invention disclosed herein and the scope of the appended claims.