WO2018208493A1 - Temporary barrier for inflow control device - Google Patents
Temporary barrier for inflow control device Download PDFInfo
- Publication number
- WO2018208493A1 WO2018208493A1 PCT/US2018/028946 US2018028946W WO2018208493A1 WO 2018208493 A1 WO2018208493 A1 WO 2018208493A1 US 2018028946 W US2018028946 W US 2018028946W WO 2018208493 A1 WO2018208493 A1 WO 2018208493A1
- Authority
- WO
- WIPO (PCT)
- Prior art keywords
- perforation
- barrier
- dissolvable
- basepipe
- elements
- Prior art date
Links
Classifications
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/02—Subsoil filtering
- E21B43/08—Screens or liners
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B33/00—Sealing or packing boreholes or wells
- E21B33/10—Sealing or packing boreholes or wells in the borehole
- E21B33/13—Methods or devices for cementing, for plugging holes, crevices, or the like
-
- 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
-
- 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
- E21B34/063—Valve or closure with destructible element, e.g. frangible disc
-
- 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
-
- 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
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/12—Methods or apparatus for controlling the flow of the obtained fluid to or in wells
-
- 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
- E21B2200/04—Ball valves
-
- 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
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
Definitions
- Reservoir completion systems installed in production, injection, and storage wells often incorporate screens positioned across the reservoir sections to prevent sand and other solids particles over a certain size from entering the reservoir completion.
- Conventional sand screen joints are typically assembled by wrapping a filter media around a perforated basepipe so fluids entering the sand screen from the wellbore must first pass through the filter media. Solid particles over a certain size will not pass through the filter media and will be prevented from entering the reservoir completion.
- a reservoir completion system 10 in Fig. 1 has completion screen joints 20 deployed on a completion string 14 in a borehole 12.
- these screen joints 20 are used for boreholes passing in an unconsolidated formation, and packers 16 or other isolation elements can be used between the various joints 20 to isolate various zones 30A-30C of the formation.
- fluid produced from the borehole 12 directs through the screen joints 20 and up the completion string 14 to the surface rig 18.
- the screen joints 20 keep out fines and other particulates in the produced fluid.
- the screen joints 20 can prevent the production of reservoir solids, can in turn mitigate erosion damage to both well and surface components, and can prevent other problems associated with fines and particulate present in the produced fluid.
- the screen joints 20 can also be used in cased holes. Additionally, the screen joints 20 can be used for gravel pack operations in which gravel [e.g., sand) is disposed in the annulus of the borehole around the screen joint 20 to support the unconsolidated formation of the open borehole 12.
- gravel e.g., sand
- An apparatus controls fluid flow in a borehole.
- the apparatus comprises a basepipe and a flow device.
- the basepipe has a through-bore conveying the fluid flow and defines at least one perforation communicating the through- bore outside the basepipe.
- the flow device comprises a barrier disposed at the at least one perforation. The barrier at least temporarily prevents fluid communication through the at least one perforation. The barrier is resistant to a pressure differential thereacross and is dissolvable over time.
- the barrier comprises at least two elements composed of different materials.
- the barrier increases the at least temporary prevention of the fluid communication in response to an increase in the pressure differential thereacross.
- the flow device can include at least one nozzle disposed relative to the at least one perforation.
- the at least one nozzle creates a pressure drop in fluid communication therethrough.
- the flow device can include a fixture affixed at the at least one perforation and defining an orifice therethrough.
- the fixture holds the barrier captive in the at least one perforation.
- the orifice of the fixture can include a nozzle disposed thereon for creating a pressure drop in fluid communication therethrough.
- the nozzle can be composed of a tungsten carbide material.
- the fixture can thread into a threaded counterbore of the at least one perforation, although other techniques can be used to affix the fixture.
- the barrier having the at least two elements of different materials comprise a plurality of barrier layers held captive in the at least one perforation with the fixture.
- the barrier layers at least temporarily prevent fluid communication between the at least one perforation of the basepipe and the orifice of the fixture.
- the barrier layers can include an inner layer of a first dissolvable material encapsulating in an outer layers of a second dissolvable material different from the first dissolvable material.
- the barrier layers can include an intermediate layer of a first dissolvable material disposed between first and second layers of a second dissolvable material different from the first dissolvable material.
- the barrier of the flow device can comprises at least two elements composed of different materials.
- a first of the at least two elements can include a plug composed of a dissolvable metal as one of the different materials.
- the plug can be affixed (threaded, welded, etc.) at the at least one perforation.
- a second of the at least two elements can include a washer composed of a dissolvable material as another of the different materials. The washer can be held captive in between the plug and the perforation.
- a first of the at least two elements can include a plug composed of a dissolvable metal as one of the different materials, and the plug can be affixed at the at least one perforation.
- a second of the at least two elements can include a coating composed of a dissolvable material as another of the different materials and coating the plug.
- the fixture can be composed of a steel material.
- the first dissolvable material can be composed of a dissolvable metallic material
- the second dissolvable material can be composed of a dissolvable gasket material.
- the apparatus can include a filter disposed on the basepipe adjacent the flow device.
- the filter filters the fluid flow from the borehole to the at least one perforation.
- the filter and the basepipe can define a gap therebetween communicating the fluid flow with the flow device.
- a housing of the flow device in fluid communication with the gap can communicating the gap with the at least one perforation.
- the housing can include at least one nozzle creating a pressure drop in the fluid flow from the gap to the at least one perforation.
- the flow device can event include at least one inflow valve permitting communication of the fluid flow in an inflow direction from the gap to the at least one perforation and preventing communication of the fluid flow in an outflow direction from the at least one perforation to the gap.
- the barrier can include a sleeve disposed inside the throughbore of the basepipe adjacent the at least one perforation. At least one seal can seal between the sleeve and the throughbore on both sides of the at least one perforation.
- the sleeve can be composed of a dissolvable metallic material, while the at least one seal can be composed of a dissolvable gasket material.
- a nozzle can be affixed at least partially in the at least one perforation.
- the at least one seal can also be a plurality of ridges defined on an exterior of the sleeve that engage an inside surface of the throughbore.
- the apparatus can be a joint for a completion string having the basepipe with the throughbore for conveying the production fluid to the surface.
- a filter or screen can be disposed on the basepipe for screening fluid produced from the surrounding borehole, although a filter or screen may not be always used.
- the flow device having the housing Disposed on the basepipe, the flow device having the housing defines a housing chamber in fluid communication with screened fluid from the screen. During production, fluid passes through the screen, enters the housing chamber, and eventually passes into the basepipe's bore through the pipe's perforations.
- the flow device disposed on the joint includes barriers as discussed herein disposed at the perforations of the basepipe.
- the flow device disposed on the joint controls fluid communication from the housing's chamber to the openings in the basepipe.
- the flow device includes one or more nozzles.
- a method for controlling fluid flow from a borehole.
- a basepipe is run into the borehole.
- the basepipe has a throughbore for conveying the fluid flow and defines at least one perforation for communicating the throughbore outside the basepipe.
- At least one barrier disposed at the at least one perforation at least temporarily prevents fluid communication through the at least one perforation.
- the at least one barrier is resistant to pressure and is dissolvable over time. Eventually, after dissolution of the at least one barrier, fluid communication is allowed through at least one nozzle disposed at the at least one perforation.
- Fig. 1 illustrates a completion system having screen joints according to the prior art deployed in a borehole.
- Fig. 2A illustrates, in partial cross-section, a screen assembly having a screen disposed on a basepipe in conjunction with an inflow control device having a temporary barrier according to the present disclosure.
- Fig. 2B illustrates, in detailed cross-section, a screen assembly having another inflow control device with a temporary barrier according to the present disclosure.
- FIG. 2C illustrates, in detailed cross-section, a screen assembly having yet another inflow control device with a temporary barrier according to the present disclosure.
- Fig. 2D illustrates, in cross-section, a basepipe having injection ports with temporary barriers of the present disclosure.
- Figs. 3A-3B illustrate a cross-sectional views of a first temporary barrier of the present disclosure.
- Fig. 4A illustrates a cross-sectional view of a second temporary barrier of the present disclosure.
- Fig. 4B illustrates a cross-sectional view of a third temporary barrier of the present disclosure.
- Fig. 4C illustrates a cross-sectional view of a fourth temporary barrier of the present disclosure.
- Figs. 4D-4E illustrate cross-sectional views of alternative elements for the temporary barriers of the present disclosure.
- Figs. 5A-5B illustrate cross-sectional views of a fifth temporary barriers of the present disclosure.
- FIG. 5C illustrate a cross-sectional views of a sixth temporary barriers of the present disclosure.
- Figs. 6A-6C illustrate cross-sectional views of seventh, eighth and ninth temporary barriers of the present disclosure.
- an apparatus 100 for controlling fluid flow in a borehole includes a basepipe 110 and a flow device 130.
- the basepipe 110 has a throughbore 112 and defines at least one perforation 115.
- the throughbore 112 conveys the fluid flow, and the at least one perforation 115 communicates the throughbore 112 outside the basepipe 110.
- the apparatus 100 can be a screen assembly, as illustrated in partial cross-section in Fig. 2A, and can have a screen 120 disposed on the basepipe 110.
- the screen 120 includes wire 122 wrapped about rods or ribs 124 disposed longitudinally along the length of the basepipe 110.
- the wire 122 is typically V-wire that filters fluid flow from the borehole to an annular space or drainage layer 125 between the wire 122 and the outside of the basepipe 110.
- the wire 122 forms various slots for screening produced fluid, and the longitudinal ribs 124 create channels that operate as a drainage layer 125.
- Other types of screen assemblies can be used for the screen 120, including metal mesh screens, pre-packed screens, protective shell screens, or screens of other construction.
- any other form filter can be used for the screen 120, including one or more layers of wire wrappings, porous metal fiber, sintered laminate, pre-packed media, etc.
- the flow device 130 is an inflow control device for the screen 120.
- the flow device 130 includes a housing 132 abutting the screen 120 and defining an interior annulus 135 communicating with the screen's drainage layer 125.
- the housing 132 is a cylindrical sleeve that slides on the basepipe 110 over a fixed end ring 134 attached to the basepipe 110.
- a threaded end ring 136 threads onto the fixed end ring 134 to keep the housing 132 abutted to the screen 120.
- the basepipe 110 defines the throughbore 112 for the passage of fluids, such as production fluids produced from the formation.
- the perforations 115 in the basepipe 110 communicate this throughbore 112 with the interior 135 of the flow device 130 so that fluid filtered through the screen 120 and entering the interior 135 can pass into the basepipe 110 to be carried to the surface.
- the apparatus 100 can be used for "gravel pack” or “fracture pack” operations or can be an openhole screen joint.
- reservoir fluids travel through the screen 120 and into the drainage layer 125 between the screen 120 and the basepipe 110.
- the produced fluid passes along the drainage layer 125 to the flow device 130. Entering the housing 132, the flow would eventually pass through the perforations 115 and in the basepipe 110.
- each of the perforations 115 include a barrier insert 150 disposed therein.
- the barrier insert 150 is resistant to pressure and is dissolvable over time so fluid passage can be at least temporarily prevented.
- the screen assembly 100 along with other completion equipment can be installed in a borehole without using an inner string because the barrier inserts 150 can keep flow of running fluid through the basepipe 110 without escaping through the perforations 115 and screen 120.
- well fluids can be displaced from the completion through the shoe while the screen assembly 100 provides isolation.
- Fig. 2B illustrates the flow device 130 of the screen assembly 100 showing the barrier insert 150 in more detail.
- the barrier insert 150 disposed at the perforation 115 includes a nozzle 160 and barrier 165.
- the nozzle 160 allows fluid communication therethrough and is designed to produce a pressure drop in the flow, such as according to the purposes of an inflow control device. Although the nozzle 160 allows fluid
- the barrier 165 at least temporarily prevents fluid communication through the perforation 115.
- the barrier 165 removes [e.g., dissolves, degrades, disintegrates, erodes, or the like) over time to open up flow through the nozzle 160.
- the barrier 165 is described as “dissolving” or being “dissolvable.” It will be appreciated with the benefit of the present disclosure that other forms of removal can also be applicable, including degrading, disintegrating, eroding, or the like.
- the flow device 130 with the nozzle 160 operates as an inflow control device to control flow of fluid into the screen assembly 100— particularly to control the flow of production fluid during production operations.
- the nozzle 160 can produce a pressure drop in the fluid, and the size and/or number of the nozzles 160 can be configured for a given implementation.
- the flow device 130 may or may not have a check valve with ball 138 and seat 137 as shown captured in the housing 132 of Fig. 2B.
- the ball 138 permits communication of the fluid flow in an inflow direction from the drainage layer 125 to the perforation 115 and prevents communication of the fluid flow in an outflow direction from the perforation 115 to the drainage layer 125.
- the barrier insert 150 with the nozzle 160 and temporary barrier 165 can be used to cover the perforations 115 for an inflow control device 130.
- the insert 150 (with or without the nozzle 160) could be used for other borehole devices, such as a limited entry liner (LEL), injection tubular, downhole tool, or other such device having a port or perforation suitable for temporary covering.
- LEL limited entry liner
- Fig. 2C illustrates an alternative arrangement in which the flow device 130 includes the nozzle 160 disposed in the housing 132 apart from the barrier insert 150 at the perforation 115 having the barrier 165.
- the barrier insert 150 does not necessarily include an integrated nozzle.
- Figs. 2A-2C show, various arrangements can be used for a flow device 130 having a nozzle 160 and barrier 165.
- Fig. 2D illustrates, in cross-section, a basepipe 110 having perforations 115 with temporary barrier inserts 150 disposed therein.
- the basepipe 110 may lack a screen assembly, although a screen could be disposed about the basepipe and perforations.
- the barrier inserts 150 can be used to temporary block the perforations 115 during injection operations, production operations, or both.
- These barrier inserts 150 have the barriers 165 and may or may not have nozzles 160 as shown.
- the temporary barrier 165 permits the screen assembly 100 (as in Figs. 2A-2C) or the plain basepipe 110 (as in Fig. 2D) to be installed in a borehole without the use of an inner string and isolates the completion string so well fluid can be displaced through the shoe of the completion.
- the temporary barrier 165 holds pressure for a range of time from hours, to days or weeks based on the particular application and well requirements.
- the temporary barrier 165 removes [e.g., dissolves, disintegrates, erodes, or the like) so the inflow control device 130 can be used for production.
- the temporary barrier 165 uses a combination of at least two different materials, including dissolvable metal, coatings, and dissolvable gasket rather than a single component, such as a rupture disk, to achieve the required delay.
- barrier inserts 150 having the barriers 165 and the optional, integrated nozzles 160 can be used, discussion turns to a particular configuration illustrated in detail in Figs. 3A-3B.
- the barrier insert 150 disposed at the perforation 115 incorporates both the nozzle 160 and the barrier 165.
- a fixture or cap 152 is affixed at the perforation 115 and defines an orifice 154
- the fixture 152 holds the barrier 165 captive in the perforation 115, and the orifice 154 of the fixture 152 includes the nozzle 160 disposed therein.
- the fixture 152 can affix in any number of ways in the perforation 115. In the present example, the fixture 152 threads into a threaded counterbore 117 of the perforation 115, but other techniques can be used that involve an interference fit, snap ring, tack weld, etc.
- the barrier 165 includes at least two barrier elements or layers composed of different materials.
- the barrier 165 includes several barrier layers 170, 172 and 174 held captive in the perforation 115 with the fixture 152.
- the barrier layers 170, 172 and 174 at least temporarily prevent fluid communication between the perforation 115 of the basepipe 110 and the orifice 154 of the fixture 152.
- the fixture 152 can include a surrounding lip forming a pocket 156 in the fixture 152. Meanwhile, profiles 158 on the fixture's external surface can facilitate threading the fixture 152 into the perforation 115.
- the fixture 152 can be composed of a steel material, and the nozzle 160 can be composed of erosion-resistant material, tungsten carbide, ceramic, or other comparable material.
- the barrier layers 170, 172, and 174 comprise an
- the metal fixture 152 traps the dissolvable metal inset 172 between the dissolvable rubber gaskets 170, 174 to
- the use of the metal inset(s) and rubber gasket(s) for the layers 170, 172, and 174 helps achieve an effective seal.
- the metal for the inset(s) can be tailored to remove [i.e., dissolve) within a specific time period as can the material of the gasket(s). Additional control over the duration of the temporary barrier 165 can be achieved by coating the dissolvable metal inset(s) with a time delay coating.
- a combination of dissolvable metal inset(s) (with or without coating) and the dissolvable rubber gasket(s) can be tailored to achieve a length of time in which the temporary barrier 165 remains in the basepipe 110 before dissolving away to leave the nozzle 160 open to flow.
- suitable material for the inset(s) includes, but is not limited to, dissolvable metallic material; reactive metal; magnesium; aluminum; powder metal; magnesium alloy; calcium, magnesium, and/or aluminum including alloying elements of calcium, magnesium, aluminum, lithium, gallium, indium, zinc, and bismuth; and the like.
- dissolution/degradation of the inset(s) can be activated by wellbore fluid, active fluid, brine, acid, and the like.
- suitable material for the gasket(s) includes, but is not limited to, elastomeric material, dissolvable/degradable rubber, degradable composite polymer, polyglycolic acid (PGA) combined with urethane, polylactic acid (PLA) combined with urethane, mixed polymers, composite of rubber beads in PGA, and the like.
- PGA polyglycolic acid
- PLA polylactic acid
- dissolution/degradation of the gasket(s) can be activated by wellbore fluid, active fluid, brine, acid, and the like.
- the temporary barrier 165 eventually removes [e.g.,
- the temporary barrier 165 uses a combination of at least two different materials, including the dissolvable metal inset 172 sandwiched between the dissolvable gaskets 170 and 174, rather than a single component, such as a rupture disk, to achieve the required delay.
- the temporary barrier 165 of the present disclosure is resistant to a pressure differential thereacross and more particularly increases the at least temporary prevention of the fluid communication through the perforation 115 in response to an increase in the pressure differential thereacross.
- the barrier 165 can achieve the pressure resistance due to the strength, thickness, material selection, shape, and/or other aspect of at least the metal inset(s).
- the metal inset of the intermediate layer 172 is a flat coin of the dissolvable metal material. Other shapes are possible.
- the barrier 165 can achieve the increased sealing due to the elements or layers 170, 172, 174 of the barrier 165 being sandwiched against one another and being pressed against the surrounding shoulders of the fixture 152 and counterbore 117 of the
- FIG. 4A shows a cross-sectional view of the barrier insert 150 lacking a nozzle 160 integrated into the cap 152.
- a separate nozzle (not shown) if desired can be installed elsewhere.
- the inside surface of the orifice 154 for the cap 152 may have a coating, or the cap 152 may be composed of a suitable erosion-resistant material to act as a nozzle for the purposes of controlling flow.
- the barrier insert 150 installed externally on the basepipe 110 into a counterbore 117 of the perforation 115.
- a reverse configuration is also possible, as shown in Fig. 4B.
- the counterbore 117 of the perforation 115 can be formed inside the bore 112 of the basepipe 110, and the barrier insert 150 can install internally.
- Such a reverse form of assembly may be needed when elements external to the basepipe 110 would obstruct the ability to install the barrier insert 150 externally.
- such a reverse form of assembly may be needed when elements external to the perforation 115 on the basepipe 110 need to be heat treated, welded, etc. during the assembly process and would damage the barrier insert 150 if already installed.
- both sides of the barrier 165 are exposed to fluid and other conditions prompting its removal.
- the barrier insert 150 included three elements or layers 170, 172, and 174. More or less elements or layers could be used as the case may be.
- Fig. 4C illustrates the barrier insert 150 having two elements or layers 170, 172 for the barrier 165. These two layers 170, 172 are preferably composed of different materials and can include a rubber gasket 170 and a metal inset 172, as shown here. The layers 170, 172 can be in either order.
- the inner pocket 156 of the fixture 152 can be coated with a dissolvable gasket material for the purposes of sealing and acting as an outer layer.
- the shoulder of the perforation could also or alternatively be coated with a dissolvable gasket material in like manner.
- Fig. 4D illustrates an example of another barrier 165 for use in the barrier insert (150) having a metal inset 173 encapsulated in a gasket shroud 171.
- This combined element 173/171 can be used alone or in combination with other elements or layers in the barrier insert (150) of the present disclosure.
- Fig. 4E illustrates another example of a barrier 165 for use in the barrier insert (150) having a metal inset 173 encapsulated in a coating 175. This too can be used alone or in combination with other elements or layers in the barrier insert (150) of the present disclosure.
- suitable material for the coating 175 can include, but is not limited to, epoxy; thermal barrier of alumina, silica, ceramic, zirconia, rare-earth oxides, metal-glass composites, etc.; anodized layer; and the like.
- Figs. 5A-5B shows cross-sectional views of a barrier insert 150 lacking a nozzle.
- the insert 150 includes a dissolvable metal plug 180 affixed [e.g., threaded) in the counterbore 117 of the perforation 115 and includes a degradable washer 182 to prevent fluid from breaching the threads and acting as a time delay.
- the threaded plug 180 can also be coated.
- a profile 188 allows a tool to thread the plug 180 into the counterbore 117 of the perforation 115.
- a dissolvable metal plug 180 is affixed [e.g., threaded and welded or inserted and welded) in the counterbore 117 of the perforation 115 to create a seal.
- a degradable washer is not used, but the threaded plug 180 can be coated.
- the barrier insert 150 includes the nozzle 160 affixed at least partially in the perforation 115 and includes the at least one barrier 165 disposed in the throughbore 112 of the basepipe 110.
- the barrier 165 is a sleeve 190 disposed inside the throughbore 112 of the basepipe 110 adjacent the perforation 115.
- At least one seal 192 seals between the sleeve 190 and the throughbore 112 on both sides of the perforation 115.
- the sleeve 190 is composed of a dissolvable metal, and the at least one seal 192 includes seal rings composed of a dissolvable rubber.
- the dissolvable metal sleeve 190 is assembled with the dissolvable rubber seal rings 192.
- the sleeve 190 which can be swaged to the interior of the basepipe's throughbore 112, is inserted into the throughbore 112. In this way, as the dissolvable metal sleeve 190 expands out, the rubber seals 192 get compressed between the two mating parts and seal the nozzle 160 temporarily.
- the sleeve 190 is not subject a pressure differential from end-to-end and would tend not to move in the bore 112. All the same, a ledge or shoulder 113 can be provided for fixing the sleeve 190.
- the dissolvable metal of the sleeve 190 reacts with completion fluid and dissolves away.
- a coating can also be applied to the inside bore of the dissolvable metal sleeve 190 to increase the duration of the temporary barrier.
- the dissolvable gasket material of the seals 192 also dissolves overtime.
- the at least one seal for the dissolvable metal sleeve 190 can alternately include a sheet 194 of dissolvable rubber formed on the outer diameter. This will form a uniform seal along the length of the sleeve 190 rather than just at both ends as described earlier.
- a reverse arrangement can be used in which the sleeve 190 and seals 192, 194 are disposed externally on the basepipe 110.
- Fig. 6C illustrates another barrier insert 150 including a nozzle 160 affixed at least partially in the perforation 115 and includes the at least one barrier 165 disposed in the throughbore 112 of the basepipe 110.
- the barrier 165 is a sleeve 190 disposed inside the throughbore 112 of the basepipe 110 adjacent the perforation 115.
- the sleeve 190 includes machined ridges 193 on its outer surface that collapse after the sleeve 190 has been swaged out to the basepipe's through-bore 112. These ridges 193 on the outer surface of the sleeve 190 act as a seal against the inside surface of the through-bore 112.
- the sleeve 190 can also be coated with a thin elastomeric coating (degradable or non-degradable) on the machined ridges 193.
Abstract
Description
Claims
Priority Applications (6)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
GB1914734.7A GB2575928A (en) | 2017-05-12 | 2018-04-23 | Temporary barrier for inflow control device |
SG11201909901R SG11201909901RA (en) | 2017-05-12 | 2018-04-23 | Temporary barrier for inflow control device |
AU2018266280A AU2018266280A1 (en) | 2017-05-12 | 2018-04-23 | Temporary barrier for inflow control device |
BR112019023863-8A BR112019023863A2 (en) | 2017-05-12 | 2018-04-23 | TEMPORARY BARRIER FOR INFLUX CONTROL DEVICE |
CA3060642A CA3060642A1 (en) | 2017-05-12 | 2018-04-23 | Temporary barrier for inflow control device |
NO20191204A NO20191204A1 (en) | 2017-05-12 | 2019-10-09 | Temporary barrier for inflow control device |
Applications Claiming Priority (2)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
US15/593,466 | 2017-05-12 | ||
US15/593,466 US20180328139A1 (en) | 2017-05-12 | 2017-05-12 | Temporary Barrier for Inflow Control Device |
Publications (1)
Publication Number | Publication Date |
---|---|
WO2018208493A1 true WO2018208493A1 (en) | 2018-11-15 |
Family
ID=62117132
Family Applications (1)
Application Number | Title | Priority Date | Filing Date |
---|---|---|---|
PCT/US2018/028946 WO2018208493A1 (en) | 2017-05-12 | 2018-04-23 | Temporary barrier for inflow control device |
Country Status (8)
Country | Link |
---|---|
US (1) | US20180328139A1 (en) |
AU (1) | AU2018266280A1 (en) |
BR (1) | BR112019023863A2 (en) |
CA (1) | CA3060642A1 (en) |
GB (1) | GB2575928A (en) |
NO (1) | NO20191204A1 (en) |
SG (1) | SG11201909901RA (en) |
WO (1) | WO2018208493A1 (en) |
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WO2021263092A1 (en) * | 2020-06-26 | 2021-12-30 | Schlumberger Technology Corporation | Interventionless injection safety valve |
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WO2018213093A1 (en) * | 2017-05-19 | 2018-11-22 | DropWise Technologies Corp. | Multi-trigger systems for controlling the degradation of degradable materials |
GB2563409A (en) * | 2017-06-14 | 2018-12-19 | Swellfix Uk Ltd | A downhole gravel packing apparatus and method |
CA3056846A1 (en) | 2018-09-25 | 2020-03-25 | Advanced Upstream Ltd. | Delayed opening port assembly |
WO2020214447A1 (en) * | 2019-04-16 | 2020-10-22 | NexGen Oil Tools Inc. | Dissolvable plugs used in downhill completion systems |
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US11346181B2 (en) * | 2019-12-02 | 2022-05-31 | Exxonmobil Upstream Research Company | Engineered production liner for a hydrocarbon well |
CA3104722A1 (en) * | 2020-01-10 | 2021-07-10 | 8Sigma Energy Services Incorporated | Downhole flow communication apparatuses |
CA3113269A1 (en) * | 2020-08-31 | 2022-02-28 | Advanced Upstream Ltd. | Port sub with delayed opening sequence |
US20220282590A1 (en) * | 2021-03-08 | 2022-09-08 | Halliburton Energy Services, Inc. | Heat hardening polymer for expandable downhole seals |
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Also Published As
Publication number | Publication date |
---|---|
US20180328139A1 (en) | 2018-11-15 |
CA3060642A1 (en) | 2018-11-15 |
AU2018266280A1 (en) | 2019-10-31 |
SG11201909901RA (en) | 2019-11-28 |
NO20191204A1 (en) | 2019-10-09 |
BR112019023863A2 (en) | 2020-06-02 |
GB201914734D0 (en) | 2019-11-27 |
GB2575928A (en) | 2020-01-29 |
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