Office Action 1: Non-Final Rejection (2025-01-28)
Rejection types: 102 - Lack of Novelty

CLAIMS:
WHAT IS CLAIMED IS:
1.A debris exclusion tool for use in a subterranean well, the debris exclusion tool comprising: a debris exclusion plug; and a tube having first and second opposite ends, the debris exclusion plug being releasably secured at the tube first end and preventing debris from falling into the tube first end, and the tube second end being configured to secure in a tubular string in the well with the second end being below the first end.
2.The debris exclusion tool of claim 1, further comprising a port that provides fluid communication between an interior and an exterior of the tube.
3.The debris exclusion tool of claim 2, in which the port is formed through a sidewall of the tube.
4.The debris exclusion tool of claim 1, in which fluid communication between an interior and an exterior of the tube is prevented by the debris exclusion plug.
5.The debris exclusion tool of claim 4, in which the debris exclusion plug is configured to release from the first end of the tube and permit fluid communication between the interior and the exterior of the tube in response to a predetermined pressure differential from the interior to the exterior of the tube.
6.The debris exclusion tool of claim 1, in which the debris exclusion plug comprises a degradable material.
7.The debris exclusion tool of claim 6, in which the degradable material is configured to degrade in a predetermined amount of time in a well environment.
8.The debris exclusion tool of claim 1, in which the debris exclusion plug is configured to dissolve in well fluid.
9.The debris exclusion tool of claim 1, further comprising a coupling configured for connection as part of a tubular string, the coupling including a flow passage extending axially through the coupling.
10.The debris exclusion tool of claim 9, in which the tube is secured to the coupling with the flow passage in fluid communication with an interior of the tube.
11.A method of establishing fluid communication through a tubular string in a subterranean well, the method comprising: blocking a first end of a tube with a debris exclusion plug; and positioning the tube within the tubular string, a second end of the tube being positioned below the first end, and an annulus being formed between the tube and the tubular string.
12.The method of claim 11, further comprising providing fluid communication between an interior and an exterior of the tube via at least one port.
13.The method of claim 12, further comprising forming the port through a sidewall of the tube.
14.The method of claim 11, in which the positioning comprises securing the second end in the tubular string above a pump-out plug that blocks fluid flow through a distal end of the tubular string.
15.The method of claim 14, further comprising applying increased pressure through an interior of the tube, thereby discharging the pump-out plug from the distal end of the tubular string.
16.The method of claim 11, in which the positioning comprises connecting the second end to a coupling connected in the tubular string.
17.The method of claim 16, in which a flow passage extends axially through the coupling, and in which the connecting comprises providing fluid communication between the flow passage and an interior of the tube.
18.The method of claim 11, further comprising applying a predetermined pressure differential from an interior to an exterior of the tube, thereby discharging the debris exclusion plug from the first end of the tube.
19.The method of claim 11, further comprising the debris exclusion plug degrading in the well.
20.The method of claim 11, further comprising the debris exclusion plug dissolving in the well.

OFFICE ACTION:
DETAILED ACTION
This action is a first action on the merits. The claims filed on January 25, 2024 have been entered. Claims 1-20 are pending and addressed below.
Notice of Pre-AIA  or AIA  Status
The present application, filed on or after March 16, 2013, is being examined under the first inventor to file provisions of the AIA .
Priority
This application claims benefit of US Provisional Application No. 63/508,839 field on June 16, 2023.
Information Disclosure Statement
The information disclosure statement filed on February 29, 2024 has been considered by the Examiner.
Claim Rejections - 35 USC § 102
In the event the determination of the status of the application as subject to AIA  35 U.S.C. 102 and 103 (or as subject to pre-AIA  35 U.S.C. 102 and 103) is incorrect, any correction of the statutory basis (i.e., changing from AIA  to pre-AIA ) for the rejection will not be considered a new ground of rejection if the prior art relied upon, and the rationale supporting the rejection, would be the same under either status.
The following is a quotation of the appropriate paragraphs of 35 U.S.C. 102 that form the basis for the rejections under this section made in this Office action:
A person shall be entitled to a patent unless –
(a)(1) the claimed invention was patented, described in a printed publication, or in public use, on sale, or otherwise available to the public before the effective filing date of the claimed invention.
Claim(s) 1-5, 9-13, and 16-18 is/are rejected under 35 U.S.C. 102(a)(1) as being anticipated by Fielder, III et al., US 2017/0328190 (hereinafter Fielder).
Claim 1: Fielder discloses a debris exclusion tool (device 10 for use in a subterranean well (device and for inhibiting particle, sand, accumulation, see abstract), the debris exclusion tool comprising:
a debris exclusion plug (check valve 21); and
a tube (central production tube 16) having first and second opposite ends (upper and lower ends shown in Fig 2), the debris exclusion plug (21) being releasably secured at the tube first end (check valve 21 opens and closes so is consider to be releasably secured) and preventing debris from falling into the tube first end (check valve 21 prevents particle flow into the tube 16, par [0024]), and the tube second end (lower end) being configured to secure in a tubular string in the well (device 10 is inserted as part of the production tubing string shown in Fig 1, production tubing 12 leading to the surface and ESP 14 located downhole adjacent to the device 10) with the second end being below the first end (lower end is below the upper end as shown in Fig 1-2).
Claim 2: Fielder discloses comprising a port (ports 24) that provides fluid communication between an interior and an exterior of the tube (a number of ports 24 are arranged along the length of the tube 16 providing fluid communication between the production tube 16 and the annulus 20, see Fig 1, par [0021]).
Claim 3: Fielder discloses in which the port (ports 24) is formed through a sidewall of the tube (12) (shown in Fig 1-2).
Claim 4: Fielder discloses in which fluid communication between an interior and an exterior of the tube (12) is prevented by the debris exclusion plug (check valve 21 prevents fluid flow into the tube 16, see Fig 2).
Claim 5: Fielder discloses the debris exclusion plug (21) is configured to release (check valve 21 opens) from the first end of the tube (16) and permit fluid communication between the interior and the exterior of the tube in response to a predetermined pressure differential from the interior to the exterior of the tube (16) (when ESP 14 turns on check valves 21, 22 immediately open and production flow through the top of tube 16 up the production tubing 12 to the surface begins, Fig 3, par [0025]).
Claim 9: Fielder discloses a coupling (enlarged cylinder housing 18) configured for connection as part of a tubular string (production tubing 12) (see Fig 1-3), the coupling including a flow passage (see arrows) extending axially through the coupling (shown in Fig 1-3).
Claim 10: Fielder discloses the tube (12) is secured to the coupling (16) (shown in Fig 1-3) with the flow passage (see arrows) in fluid communication with an interior of the tube (16) (shown in Fig 1-3, par [0023], [0025]).
Claim 11: Fielder discloses a method of establishing fluid communication through a tubular string in a subterranean well (see Fig 1-3, abstract, par [0008]), the method comprising:
blocking (via check valve 21) a first end (upper end) of a tube (16) with a debris exclusion plug (check valve 21); and
positioning the tube (16) within the tubular string (device 10 is inserted as part of the production tubing string shown in Fig 1, production tubing 12 leading to the surface and ESP 14 located downhole adjacent to the device 10), a second end of the tube (lower end) being positioned below the first end (upper end) (see Fig 1-3), and an annulus (annulus 20) being formed between the tube 16) and the tubular string (enlarged cylinder housing 18 is part of tubular string) (see Fig 1-3).
Claim 12: Fielder discloses further comprising providing fluid communication between an interior and an exterior of the tube (16) via at least one port (ports 24)( a number of ports 24 are arranged along the length of the tube 16 providing fluid communication between the production tube 16 and the annulus 20, see Fig 1, par [0021]).
Claim 13: Fielder discloses further comprising forming the port (ports 24) through a sidewall of the tube (12) (shown in Fig 1-2).
Claim 16: Fielder discloses the positioning comprises connecting the second end (lower end) to a coupling (enlarged cylinder housing 18, shown in Fig 1-3) connected in the tubular string  (production tubing 12) (see Fig 1-3).
Claim 17: Fielder discloses a flow passage (see arrows) extends axially through the coupling (18), and in which the connecting comprises providing fluid communication (shown via arrows) between the flow passage arrows, Fig 1-3) and an interior of the tube (6) (see Fig 1).
Claim 18: Fielder discloses further comprising applying a predetermined pressure differential (via ESP 14) from an interior to an exterior of the tube (see Fig 3), thereby discharging the debris exclusion plug (21) from the first end of the tube (when ESP 14 turns on check valves 21, 22 immediately open and production flow through the top of tube 16 up the production tubing 12 to the surface begins, Fig 3, par [0025]).
Claim(s) 1, 4-7, 11, and 18-19 is/are rejected under 35 U.S.C. 102(a)(1) as being anticipated by McFarlin et al., US 2022/0341279 (hereinafter McFarlin).
Claim 1: McFarlin discloses a debris exclusion tool for use in a subterranean well (see Fig 2), the debris exclusion tool comprising:
a debris exclusion plug (plug 28); and
a tube (tubular mandrel 32) having first and second opposite ends (upper and lower ends shown in Fig 2), the debris exclusion plug (28) being releasably secured at the tube first end (see Fig 23, internal plug 28 can be removable, par [0019]) and preventing debris from falling into the tube first end, and the tube second end (lower end) being configured to secure in a tubular string in the well (slips 36 are radially outwardly extended into gripping engagement with the casing, see Fig 2, par [0036]) with the second end being below the first end (lower end is below the upper end as shown in Fig 2).
Claim 4: McFarlin discloses in which fluid communication between an interior and an exterior of the tube is prevented by the debris exclusion plug (plug 28) (plug 28 is installed in the flow passage 26 and sealingly engaged therein, so that fluid communication is prevented between upper and lower sections of the wellbore 12, par [0016]).
Claim 5: McFarlin discloses in which the debris exclusion plug (28) is configured to release from the first end (upper end) of the tube (32) and permit fluid communication between the interior and the exterior of the tube (32) in response to a predetermined pressure differential from the interior to the exterior of the tube (sufficient positive pressure differential from above is applied to the plug 42, the shear member 44 will shear, par [0026]-[0027]).
Claim 6: McFarlin discloses the debris exclusion plug (28) comprises a degradable material (shear material 44, shearing is considered degrading).
Claim 7: McFarlin discloses in which the degradable material is configured to degrade in a predetermined amount of time in a well environment (shear material 44, shearing is considered degrading which occurs in predetermined amount of time in this case on reaching sufficient positive pressure differential, par [0026]-[0027]).
Claim 11: McFarlin discloses a method of establishing fluid communication through a tubular string in a subterranean well (fluid communication permitted between the upper and lower sections of the wellbore 12, abstract, par [0028]) , the method comprising:
blocking a first end (upper end) of a tube (tubular mandrel 32) with a debris exclusion plug (plug 28); and
positioning the tube (32) within the tubular string (12) (tubular mandrel 32 is part of barrier 24 located positioned in wellbore 12), a second end (lower end) of the tube (32) being positioned below the first end (upper end), and an annulus (annulus above and below seal 40 between mandrel 32 and   wellbore 12) being formed between the tube (32) and the tubular string (12) (see Figures 1-2).
Claim 18: McFarlin discloses comprising applying a predetermined pressure differential from an interior to an exterior of the tube (sufficient pressure differential from below can be applied to the plug 28, when shear strength of the shear member 44 is exceeded), thereby discharging the debris exclusion plug (28) from the first end of the tube (32) (shear member 44 is sheared, the plug 28 will no longer be secured in the flow passage 26, and fluid communication will then be permitted between the upper and lower sections of the wellbore 12 (above and below the barrier 24) through the flow passage, par [0028]-[0029]).
Claim 19: McFarlin discloses the debris exclusion plug (28) degrading in the well (shear material 44, shearing is considered degrading).
Claim(s) 1 and 11 is/are rejected under 35 U.S.C. 102(a)(1) as being anticipated by Head, WO 2023/131805 (hereinafter Head)
Claim 1: Head discloses a debris exclusion tool for use in a subterranean well, the debris exclusion tool comprising:
a debris exclusion plug (fragmentable cap 55); and
a tube (bridge plug mandrel 50) having first and second opposite ends (shown in Fig 8), the debris exclusion plug (55) being releasably secured at the tube first end and preventing debris from falling into the tube first end (fragmentable cap 55 prevent debris from falling into the inner bore 51 of the mandrel 50 located at upper end), and the tube second end being configured to secure in a tubular string (well casing 1) in the well with the second end being below the first end (shown in Fig 8).
Claim 11: Head discloses a method of establishing fluid communication through a tubular string in a subterranean well, the method comprising:
blocking a first end (upper end) of a tube (bridge plug mandrel 50) with a debris exclusion plug (fragmentable cap 55) (Fig 8, pg 8, ln 30 – pg 9, ln 5); and
positioning the tube (50) within the tubular string (well casing 1) (as shown in Fig 8),
a second end (lower end) of the tube being positioned below the first end (upper end), and an annulus being formed between the tube (50) and the tubular string (well casing) (annulus formed between bridge plug mandrel 50 and well casing at the upper end near fragmentable cap 55 as shown in Fig 8).
Claim(s) 1, 6-8, 11 and 20 is/are rejected under 35 U.S.C. 102(a)(1) as being anticipated by Fripp et al., US 2019/0144733 (hereinafter Fripp).
Claim 1: Fripp discloses a debris exclusion tool (sealing ball 208) for use in a subterranean well (110/112), the debris exclusion tool comprising:
a debris exclusion plug (sealing ball 208) (sealing ball 208 would exclude debris by nature of sealing); and
a tube (mandrel 206) having first and second opposite ends (upper and lower ends of mandrel 206), the debris exclusion plug (208) being releasably secured at the tube first end (upper end) and preventing debris from falling into the tube first end (sealing ball 208 may be dropped into the conveyance 118 to land on top of the wellbore isolation device 200, see Fig 1-2, par [0023], seal would necessarily prevent debris), and the tube second end (lower end) being configured to secure in a tubular string (string of casing 114) in the well (wellbore 110/112) with the second end (lower end) being below the first end (upper end).
Claim 6: Fripp discloses the debris exclusion plug (208) comprises a degradable material (wellbore isolation device 200 proceeds to dissolve and/or degrade, par [0032]).
Claim 7: Fripp disclose, in which the degradable material (208) is configured to degrade in a predetermined amount of time in a well environment (wellbore isolation device 200 proceeds to dissolve and/or degrade, par [0032], degradation necessarily takes a predetermine amount of time).
Claim 8: Fripp discloses the debris exclusion plug (208) is configured to dissolve in well fluid (wellbore isolation device 200 proceeds to dissolve and/or degrade, par [0032]).
Claim 11: Fripp discloses a method of establishing fluid communication through a tubular string (casing string 114) in a subterranean well (wellbore 110/112) (Fig 1-2, par [0026]), the method comprising:
blocking a first end (upper end) of a tube (mandrel 206)  with a debris exclusion plug (sealing ball 206) (sealing ball 208 may be dropped into the conveyance 118 to land on top of the wellbore isolation device 200, see Fig 1-2, par [0023], seal would necessarily prevent debris); and
positioning the tube (206) within the tubular string (string of casing 114) (see Fig 2), a second end (lower end) of the tube (206) being positioned below the first end (upper end), and an annulus (between mandrel 206 and string of casing 114 above and below inflatable packer elements 220) being formed between the tube (206) and the tubular string (114) (see Fig 2).
Claim 20: Fripp discloses the debris exclusion plug (208) dissolving in the well (wellbore isolation device 200 proceeds to dissolve and/or degrade, par [0032]).
Allowable Subject Matter
Claims 14-15 are objected to as being dependent upon a rejected base claim, but would be allowable if rewritten in independent form including all of the limitations of the base claim and any intervening claims.
Regarding claim 14-15, Fielder, McFarlin, and Head fail to disclose the positioning comprises securing the second end in the tubular string above a pump-out plug that blocks fluid flow through a distal end of the tubular string.
It would not have been obvious to one of ordinary skill in the art, to secure the second end in the tubular string above a plump-out plug that blocks fluid flow through a distal end of the tubular string, as the second end disclosed by Fielder is already attached to an ESP, the second end of McFarlin is required to be open, and the second end of Head is attached to an empty housing and modification of Fielder, McFarlin, or Head such that the such that the second end is secured above a pump-out plug that blocks fluid flow through a distal end of the tubular string, would destroy the intended purpose of Fielder, McFarlin, or Head.
Conclusion
Claims 1-13 and 16-20 are rejected. Claims 14-15 are objected to.


NEXT OFFICE ACTION: DETAILED ACTION
This action is in response to the Applicant’s Reply filed on March 28, 2025. Claims 1-20 are pending and addressed below.
Response to Amendment
Claims 1, 4-5, 11, and 14 have been amended. Claims 1-20 are pending and addressed below.
Reasons for Allowance
The following is an examiner’s statement of reasons for allowance: The claims are allowable over the closest prior art “herein Fielder, III et al., US 2017/0328190 (hereinafter Fielder)” and “herein McFarlin et al., US 2022/0341279 (hereinafter McFarlin)”, for the following reasons:
Fielder discloses a debris exclusion tool (device 10) for use in a subterranean well (device and for inhibiting particle, sand, accumulation, see abstract), including a debris exclusion plug (check valve 21); and a tube (central production tube 16) having first and second opposite ends (upper and lower ends shown in Fig 2), the debris exclusion plug (21) being releasably secured at the tube first end (check valve 21 opens and closes so is consider to be releasably secured) and preventing debris from falling into the tube first end (check valve 21 prevents particle flow into the tube 16, par [0024]), and the tube second end (lower end) being configured to secure in a tubular string in the well (device 10 is inserted as part of the production tubing string shown in Fig 1, production tubing 12 leading to the surface and ESP 14 located downhole adjacent to the device 10) with the second end being below the first end (lower end is below the upper end as shown in Fig 1-2).
Fielder fails to disclose the second end being disposed in the tubular string above a pump-out plug that is configured to block fluid flow through a distal end of the tubular sting.
McFarlin discloses a debris exclusion tool for use in a subterranean well (see Fig 2), the debris exclusion tool comprising: a debris exclusion plug (plug 28); and a tube (tubular mandrel 32) having first and second opposite ends (upper and lower ends shown in Fig 2), the debris exclusion plug (28) being releasably secured at the tube first end (see Fig 23, internal plug 28 can be removable, par [0019]) and preventing debris from falling into the tube first end, and the tube second end (lower end) being configured to secure in a tubular string in the well (slips 36 are radially outwardly extended into gripping engagement with the casing, see Fig 2, par [0036]) with the second end being below the first end (lower end is below the upper end as shown in Fig 2).
McFarlin fails to disclose the second end being disposed in the tubular string above a pump-out plug that is configured to block fluid flow through a distal end of the tubular sting.
It would not have been obvious to one of ordinary skill in the art, to secure the second end in the tubular string above a plump-out plug that blocks fluid flow through a distal end of the tubular string, as the second end disclosed by Fielder is already attached to an ESP and the second end of McFarlin is required to be open, and modification of Fielder or McFarlin, such that the such that the second end is secured above a pump-out plug that blocks fluid flow through a distal end of the tubular string, would destroy the intended purpose of Fielder and  McFarlin.
Fielder and McFarlin fail to suggest alone, or in combination, the limitations of
“the second end being disposed in the tubular string above a pump-out plug that is configured to block fluid flow through a distal end of the tubular sting” as recited in claim 1; and
“positioning the tube within the tubular string above a pump-out plug that is configured to block flow through a distal end of the tubular string” as recited in claim 11.
The Examiner is unaware of prior art that reasonably suggests alone, or in combination, the limitations of the invention as claimed.
Any comments considered necessary by applicant must be submitted no later than the payment of the issue fee and, to avoid processing delays, should preferably accompany the issue fee.  Such submissions should be clearly labeled “Comments on Statement of Reasons for Allowance.”
Conclusion

CITED REFERENCE SUMMARIES: Ref US20170328190A1: [content unavailable]
Ref US20220341279A1: Claims:
A well barrier for use in a subterranean well, the well barrier comprising: an inner mandrel; a flow passage extending longitudinally through the inner mandrel; and a plug releasably secured relative to the inner mandrel, the plug blocking fluid flow through the flow passage, and the plug including a shoulder that prevents the plug from displacing completely through the inner mandrel in a first longitudinal direction.
an inner mandrel;
a flow passage extending longitudinally through the inner mandrel; and
a plug releasably secured relative to the inner mandrel, the plug blocking fluid flow through the flow passage, and the plug including a shoulder that prevents the plug from displacing completely through the inner mandrel in a first longitudinal direction.
The well barrier of claim 1 , in which at least one seal is sealingly engaged between the plug and the flow passage.
The well barrier of claim 2 , in which the at least one seal comprises first and second seals, a body of the plug is coated with a coating material, and an area longitudinally between the first and second seals is not coated with the coating material.
The well barrier of claim 3 , in which a degrading material is positioned in the body of the plug.
The well barrier of claim 1 , in which the plug is releasable for displacement out of the inner mandrel in response to application of a positive pressure differential in the first longitudinal direction.
The well barrier of claim 1 , in which the plug is releasable for displacement out of the inner mandrel in response to application of a positive pressure differential in a second longitudinal direction opposite to the first longitudinal direction.
The well barrier of claim 1 , in which a shear member releasably secures the plug in the flow passage.
- 20 . (canceled)
Ref US20190144733A1: Claims:
A wellbore isolation device comprising: a component selected from the group consisting of a mandrel, a packer element, a sealing ball, a wedge, a slip, a mule shoe, a wiper element, a wiper body, and any combination thereof; wherein the component comprises a degradable non-metallic material that degrades upon exposure to a wellbore environment; and wherein the degradable non-metallic material is a composite material comprising a non-epoxy matrix material and a reinforcing material.
a component selected from the group consisting of a mandrel, a packer element, a sealing ball, a wedge, a slip, a mule shoe, a wiper element, a wiper body, and any combination thereof; wherein the component comprises a degradable non-metallic material that degrades upon exposure to a wellbore environment; and wherein the degradable non-metallic material is a composite material comprising a non-epoxy matrix material and a reinforcing material.
The wellbore isolation device of claim 1 , wherein the matrix material comprises a polyurethane rubber; a polyester-based polyurethane rubber; a polyether-based polyurethane rubber; a thiol-based polymer; a thiol-epoxy polymer; a hyaluronic acid rubber; a polyhydroxobutyrate rubber; a polyester elastomer; a polyester amide elastomer; a starch-based resin; a polyethylene terephthalate polymer; a polyester thermoplastic; a polyglycolic acid polymer; a polylactic acid polymer; a polybutylene succinate polymer; a polyhydroxy alkanoic acid polymer; a polybutylene terephthalate polymer; a polysaccharide; chitin; chitosan; a protein; an aliphatic polyester; poly(Îµ-caprolactone); a poly(hydroxybutyrate); poly(ethyleneoxide); poly(phenyllactide); a poly(amino acid); a poly(orthoester); polyphosphazene; a polylactide; a polyglycolide; a poly(anhydride); a polyepichlorohydrin; a copolymer of ethylene oxide/polyepichlorohydrin; a terpolymer of epichlorohydrin/ethylene oxide/allyl glycidyl ether; copolymers thereof; terpolymers thereof; or any combination thereof.
The wellbore isolation device of claim 1 , wherein the matrix material is an elastomer.
The wellbore isolation device of claim 1 , wherein the reinforcing material is a particulate material selected from the group consisting of organophilic clay, silica flour, metals, metal oxide, silicates, aluminosilicates, carbon, sand, bauxite, ceramic materials, silicon carbide, alumina, glass materials, polymer materials, polytetrafluoroethylene materials, nut shell pieces, cured resinous particulates comprising nut shell pieces, seed shell pieces, cured resinous particulates comprising seed shell pieces, fruit pit pieces, cured resinous particulates comprising fruit pit pieces, wood, minerals, composite particulates, and any combination thereof.
The wellbore isolation device of claim 1 , wherein the reinforcing material is a fiber material selected from the group consisting of carbon fibers, carbon nanotubes, carbon black, graphene, fullerene, a ceramic fiber, a plastic fiber, a glass fiber, a metal fiber, silica fibers, natural fibers, and any combination thereof.
The wellbore isolation device of claim 5 , wherein the fiber has a length-to-diameter ratio in excess of 5:1.
The wellbore isolation device of claim 1 , wherein the component is a first component and wherein the wellbore isolation device comprises a second component selected from the group consisting of a mandrel, a packer element, a sealing ball, a wedge, a slip, a mule shoe, a wiper element, a wiper body, and any combination thereof; wherein the second component comprises a degradable metal material.
The wellbore isolation device of claim 1 , wherein the component is a first component and wherein the wellbore isolation device comprises a second component selected from the group consisting of a mandrel, a packer element, a sealing ball, a wedge, a slip, a mule shoe, a wiper element, a wiper body, and any combination thereof; wherein the second component comprises a degradable metal material; wherein the wellbore isolation device comprises a third component selected from the group consisting of a mandrel, a packer element, a sealing ball, a wedge, a slip, a mule shoe, a wiper element, a wiper body, and any combination thereof; wherein the third component comprises a degradable elastomer.
The wellbore isolation device of claim 1 , wherein the component is a first component and wherein the wellbore isolation device comprises a second component selected from the group consisting of a mandrel, a packer element, a sealing ball, a wedge, a slip, a mule shoe, a wiper element, a wiper body, and any combination thereof; wherein the degradable non-metallic material is a first degradable non-metallic material; wherein the second component comprises a second degradable non-metallic material; wherein the second degradable non-metallic material is a non-composite material.
The wellbore isolation device of claim 1 , wherein the component is a first component and wherein the wellbore isolation device comprises a second component selected from the group consisting of a mandrel, a packer element, a sealing ball, a wedge, a slip, a mule shoe, a wiper element, a wiper body, and any combination thereof; wherein the second component comprises a degradable glass material.
The wellbore isolation device of claim 1 , wherein the non-epoxy matrix material comprises polyglycolic acid; and wherein the reinforcing material comprises a glass fiber having a length of about two inches or less.
A method comprising: introducing a downhole tool into a wellbore, wherein the downhole tool is a wellbore isolation device comprising at least one component selected from the group consisting of a mandrel, a packer element, a sealing ball, a wedge, a slip, a mule shoe, a wiper element, a wiper body, and any combination thereof; wherein the component comprises a degradable non-metallic material that degrades upon exposure to a wellbore environment; and wherein the degradable non-metallic material is a composite material comprising a non-epoxy matrix material and a reinforcing material; anchoring the downhole tool within the wellbore at a target location; performing at least one downhole operation; and degrading the degradable non-metallic material upon exposure to a wellbore environment.
introducing a downhole tool into a wellbore, wherein the downhole tool is a wellbore isolation device comprising at least one component selected from the group consisting of a mandrel, a packer element, a sealing ball, a wedge, a slip, a mule shoe, a wiper element, a wiper body, and any combination thereof; wherein the component comprises a degradable non-metallic material that degrades upon exposure to a wellbore environment; and wherein the degradable non-metallic material is a composite material comprising a non-epoxy matrix material and a reinforcing material;
anchoring the downhole tool within the wellbore at a target location;
performing at least one downhole operation; and
degrading the degradable non-metallic material upon exposure to a wellbore environment.
The method of claim 12 , wherein the matrix material comprises a polyurethane rubber; a polyester-based polyurethane rubber; a polyether-based polyurethane rubber; a thiol-based polymer; a thiol-epoxy polymer; a hyaluronic acid rubber; a polyhydroxobutyrate rubber; a polyester elastomer; a polyester amide elastomer; a starch-based resin; a polyethylene terephthalate polymer; a polyester thermoplastic; a polyglycolic acid polymer; a polylactic acid polymer; a polybutylene succinate polymer; a polyhydroxy alkanoic acid polymer; a polybutylene terephthalate polymer; a polysaccharide; chitin; chitosan; a protein; an aliphatic polyester; poly(Îµ-caprolactone); a poly(hydroxybutyrate); poly(ethyleneoxide); poly(phenyllactide); a poly(amino acid); a poly(orthoester); polyphosphazene; a polylactide; a polyglycolide; a poly(anhydride); a polyepichlorohydrin; a copolymer of ethylene oxide/polyepichlorohydrin; a terpolymer of epichlorohydrin/ethylene oxide/allyl glycidyl ether; copolymers thereof; terpolymers thereof; or any combination thereof.
The method of claim 12 , wherein the reinforcing material is a particulate material selected from the group consisting of organophilic clay, silica flour, metals, metal oxide, silicates, aluminosilicates, carbon, sand, bauxite, ceramic materials, silicon carbide, alumina, glass materials, polymer materials, polytetrafluoroethylene materials, nut shell pieces, cured resinous particulates comprising nut shell pieces, seed shell pieces, cured resinous particulates comprising seed shell pieces, fruit pit pieces, cured resinous particulates comprising fruit pit pieces, wood, minerals, composite particulates, and any combination thereof.
The method of claim 12 , wherein the reinforcing material is a fiber material selected from the group consisting of carbon fibers, carbon nanotubes, carbon black, graphene, fullerene, a ceramic fiber, a plastic fiber, a glass fiber, a metal fiber, silica fibers, natural fibers, and any combination thereof.
The method of claim 12 , wherein the component is a first component and wherein the wellbore isolation device comprises a second component selected from the group consisting of a mandrel, a packer element, a sealing ball, a wedge, a slip, a mule shoe, a wiper element, a wiper body, and any combination thereof; wherein the second component comprises a degradable metal material.
The method of claim 12 , wherein the component is a first component and wherein the wellbore isolation device comprises a second component selected from the group consisting of a mandrel, a packer element, a sealing ball, a wedge, a slip, a mule shoe, a wiper element, a wiper body, and any combination thereof; wherein the degradable non-metallic material is a first degradable non-metallic material; wherein the second component comprises a second degradable non-metallic material; wherein the second degradable non-metallic material is a non-composite material.
The method of claim 12 , wherein the component is a first component and wherein the wellbore isolation device comprises a second component selected from the group consisting of a mandrel, a packer element, a sealing ball, a wedge, a slip, a mule shoe, a wiper element, a wiper body, and any combination thereof; wherein the second component comprises a degradable glass material.
A system comprising: a conveyance connected to a service rig and extending through a surface into a wellbore in a subterranean formation; and a downhole tool connected to the conveyance and placed in the wellbore, wherein the downhole tool is a wellbore isolation device comprising at least one component selected from the group consisting of a mandrel, a packer element, a sealing ball, a wedge, a slip, a mule shoe, a wiper element, a wiper body, and any combination thereof; wherein the component comprises a degradable non-metallic material that degrades upon exposure to a wellbore environment; and wherein the degradable non-metallic material is a composite material comprising a non-epoxy matrix material and a reinforcing material.
a conveyance connected to a service rig and extending through a surface into a wellbore in a subterranean formation; and
a downhole tool connected to the conveyance and placed in the wellbore, wherein the downhole tool is a wellbore isolation device comprising at least one component selected from the group consisting of a mandrel, a packer element, a sealing ball, a wedge, a slip, a mule shoe, a wiper element, a wiper body, and any combination thereof; wherein the component comprises a degradable non-metallic material that degrades upon exposure to a wellbore environment; and wherein the degradable non-metallic material is a composite material comprising a non-epoxy matrix material and a reinforcing material.
The system of claim 19 , wherein the matrix material comprises a polyurethane rubber; a polyester-based polyurethane rubber; a polyether-based polyurethane rubber; a thiol-based polymer; a thiol-epoxy polymer; a hyaluronic acid rubber; a polyhydroxobutyrate rubber; a polyester elastomer; a polyester amide elastomer; a starch-based resin; a polyethylene terephthalate polymer; a polyester thermoplastic; a polyglycolic acid polymer; a polylactic acid polymer; a polybutylene succinate polymer; a polyhydroxy alkanoic acid polymer; a polybutylene terephthalate polymer; a polysaccharide; chitin; chitosan; a protein; an aliphatic polyester; poly(Îµ-caprolactone); a poly(hydroxybutyrate); poly(ethyleneoxide); poly(phenyllactide); a poly(amino acid); a poly(orthoester); polyphosphazene; a polylactide; a polyglycolide; a poly(anhydride); a polyepichlorohydrin; a copolymer of ethylene oxide/polyepichlorohydrin; a terpolymer of epichlorohydrin/ethylene oxide/allyl glycidyl ether; copolymers thereof; terpolymers thereof; or any combination thereof.
The system of claim 19 , wherein the component is a first component and wherein the wellbore isolation device comprises a second component selected from the group consisting of a mandrel, a packer element, a sealing ball, a wedge, a slip, a mule shoe, a wiper element, a wiper body, and any combination thereof; wherein the second component comprises a degradable metal material.
The system of claim 19 , wherein the component is a first component and wherein the wellbore isolation device comprises a second component selected from the group consisting of a mandrel, a packer element, a sealing ball, a wedge, a slip, a mule shoe, a wiper element, a wiper body, and any combination thereof; wherein the degradable non-metallic material is a first degradable non-metallic material; wherein the second component comprises a second degradable non-metallic material; wherein the second degradable non-metallic material is a non-composite material.
Ref WO2023131805A1: [content unavailable]
Ref US20170328190: Claims:
1. A device for preventing particle interference with lifting equipment in a well bore having a production tubing string, comprising:
an elongated tube positioned between the lifting equipment and the surface and in fluid communication with the lifting equipment and the production tubing string; a housing positioned around the tube defining an annulus portion between the tube and housing; a check valve connected to the tube proximate the distal end of the tube nearest the lifting equipment operable to permit fluid flow from the lifting equipment into the tube and to prevent fluid flow from the tube to the lifting equipment; a plurality of ports positioned in the wall of the tube operable to permit fluid flow from the tube into the annulus during operation of the lifting equipment and operable to inhibit particles from entering the tube when the lifting equipment is not operating, wherein the ports are spaced along the tube and oriented at an acute angle to the longitudinal axis of the elongated tube relative to the distal end.
2. The device of claim 1, wherein the lifting equipment is an electric submersible pump (ESP).
3. The device of claim 1, wherein the ports are oriented in a direction opposite the direction of fluid flow in the tube during operation of the lifting equipment.
4. The device of claim 1, wherein the ports are at an acute angle between 30-60′ relative to the wall of the tube.
5. The device of claim 1, wherein the largest number of ports are positioned nearest the distal end.
6. The device of claim 5, wherein the fewest number of ports are positioned nearest the proximal end.
7. The device of claim 1, including an outer cylinder surrounding the tube and defining the annulus between the tube and the cylinder.
8. The device of claim 1, wherein the well bore includes a horizontal section and the lifting equipment and device are positioned in the horizontal section.
9. The device of claim 1, wherein the ports have an angle and size that, along with the given thickness of the tube, inhibit particles from movement into the tube when the operation of the lifting equipment is stopped.
10. A method of operating lifting equipment in a well bore comprising:
positioning the lifting equipment in the well bore downhole from the surface and operable to pump fluid through a production tubing string to the surface; connecting a particle inhibiting device to the production tubing string between the lifting equipment and the surface, the device having a central tubular portion, a surrounding annulus portion, and a plurality of spaced ports communicating there between, and a check valve operable to prevent fluid flow from the tube in the direction of the lifting equipment; operating the lifting equipment to flow fluid into the tubular portion through the ports into the annulus portion and into the production tubing; and containing particles in the fluid from accumulating on the lifting equipment when the lifting equipment is not in use by trapping a substantial portion of particles in the annulus, whereby the ports inhibit particle flow into the tubing portion and the check valve prevents fluid flow in the direction of the lifting equipment.
11. The method of claim 10, including preventing fluid from flowing in the tubular portion when the lifting equipment is not in use using the ports and a cap on the tubular portion.
12. The method of claim 10, including preventing fluid from flowing to the lifting equipment when the lifting equipment is not in use using said check valve and allowing fluid flow from the lifting equipment into the tube when the lifting equipment is in use.
13. The method of claim 10, the tubular portion defined by an end cap at a proximal end and the check valve at the distal end, the ports being more dense closest to the distal end.
14. The method of claim 10, operating the lifting equipment after particles have accumulated in the annular portion to expel the particles into the production tubing towards the surface.
15. The method of claim 10, the ports being oriented at an acute angle to the longitudinal axis of the elongated tube relative to the distal end, when the lifting equipment is not i
[Truncated to input limit]