US20030213596A1 - Tubular goods and liners - Google Patents
Tubular goods and liners Download PDFInfo
- Publication number
- US20030213596A1 US20030213596A1 US10/366,936 US36693603A US2003213596A1 US 20030213596 A1 US20030213596 A1 US 20030213596A1 US 36693603 A US36693603 A US 36693603A US 2003213596 A1 US2003213596 A1 US 2003213596A1
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- Prior art keywords
- tubular good
- tubular
- layer
- liner
- good
- Prior art date
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- Abandoned
Links
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- 238000009792 diffusion process Methods 0.000 claims abstract description 30
- 239000000126 substance Substances 0.000 claims abstract description 15
- 239000010410 layer Substances 0.000 claims description 61
- 238000000034 method Methods 0.000 claims description 23
- -1 polyethylene Polymers 0.000 claims description 20
- 239000004743 Polypropylene Substances 0.000 claims description 15
- 229920001155 polypropylene Polymers 0.000 claims description 15
- 239000012790 adhesive layer Substances 0.000 claims description 9
- 239000000654 additive Substances 0.000 claims description 7
- 229920001577 copolymer Polymers 0.000 claims description 7
- 230000032258 transport Effects 0.000 claims description 7
- 239000004698 Polyethylene Substances 0.000 claims description 5
- 238000005065 mining Methods 0.000 claims description 5
- 229920000573 polyethylene Polymers 0.000 claims description 5
- IMROMDMJAWUWLK-UHFFFAOYSA-N Ethenol Chemical compound OC=C IMROMDMJAWUWLK-UHFFFAOYSA-N 0.000 claims description 4
- 229920001519 homopolymer Polymers 0.000 claims description 4
- 229920000098 polyolefin Polymers 0.000 claims description 4
- 239000002002 slurry Substances 0.000 claims description 4
- 239000012530 fluid Substances 0.000 claims description 3
- 238000004519 manufacturing process Methods 0.000 claims description 3
- 239000003082 abrasive agent Substances 0.000 claims description 2
- 238000005086 pumping Methods 0.000 claims description 2
- 150000001875 compounds Chemical class 0.000 claims 4
- 230000000996 additive effect Effects 0.000 claims 3
- 239000000853 adhesive Substances 0.000 abstract description 6
- 230000001070 adhesive effect Effects 0.000 abstract description 6
- 238000005260 corrosion Methods 0.000 abstract description 5
- 230000007797 corrosion Effects 0.000 abstract description 5
- 239000000463 material Substances 0.000 description 12
- 239000007789 gas Substances 0.000 description 8
- VNWKTOKETHGBQD-UHFFFAOYSA-N methane Chemical compound C VNWKTOKETHGBQD-UHFFFAOYSA-N 0.000 description 8
- 229910052751 metal Inorganic materials 0.000 description 7
- 239000002184 metal Substances 0.000 description 7
- 229920000642 polymer Polymers 0.000 description 7
- CURLTUGMZLYLDI-UHFFFAOYSA-N Carbon dioxide Chemical compound O=C=O CURLTUGMZLYLDI-UHFFFAOYSA-N 0.000 description 6
- 229910002092 carbon dioxide Inorganic materials 0.000 description 5
- 239000007788 liquid Substances 0.000 description 5
- 230000008878 coupling Effects 0.000 description 4
- 238000010168 coupling process Methods 0.000 description 4
- 238000005859 coupling reaction Methods 0.000 description 4
- 239000003345 natural gas Substances 0.000 description 4
- 230000003247 decreasing effect Effects 0.000 description 3
- 239000003209 petroleum derivative Substances 0.000 description 3
- 238000005553 drilling Methods 0.000 description 2
- 238000000605 extraction Methods 0.000 description 2
- FPYJFEHAWHCUMM-UHFFFAOYSA-N maleic anhydride Chemical compound O=C1OC(=O)C=C1 FPYJFEHAWHCUMM-UHFFFAOYSA-N 0.000 description 2
- 238000012986 modification Methods 0.000 description 2
- 230000004048 modification Effects 0.000 description 2
- 239000003208 petroleum Substances 0.000 description 2
- 239000000243 solution Substances 0.000 description 2
- 241000894006 Bacteria Species 0.000 description 1
- RWSOTUBLDIXVET-UHFFFAOYSA-N Dihydrogen sulfide Chemical compound S RWSOTUBLDIXVET-UHFFFAOYSA-N 0.000 description 1
- 238000006424 Flood reaction Methods 0.000 description 1
- 239000004372 Polyvinyl alcohol Substances 0.000 description 1
- 241000282887 Suidae Species 0.000 description 1
- 238000005299 abrasion Methods 0.000 description 1
- 230000001133 acceleration Effects 0.000 description 1
- 239000013543 active substance Substances 0.000 description 1
- 239000000956 alloy Substances 0.000 description 1
- 229910045601 alloy Inorganic materials 0.000 description 1
- QVGXLLKOCUKJST-UHFFFAOYSA-N atomic oxygen Chemical compound [O] QVGXLLKOCUKJST-UHFFFAOYSA-N 0.000 description 1
- 239000001569 carbon dioxide Substances 0.000 description 1
- 239000011248 coating agent Substances 0.000 description 1
- 238000000576 coating method Methods 0.000 description 1
- 238000010410 dusting Methods 0.000 description 1
- 238000001125 extrusion Methods 0.000 description 1
- 229910000037 hydrogen sulfide Inorganic materials 0.000 description 1
- 238000002347 injection Methods 0.000 description 1
- 239000007924 injection Substances 0.000 description 1
- 229910010272 inorganic material Inorganic materials 0.000 description 1
- 239000011147 inorganic material Substances 0.000 description 1
- 238000003780 insertion Methods 0.000 description 1
- 230000037431 insertion Effects 0.000 description 1
- 150000002739 metals Chemical class 0.000 description 1
- 230000002906 microbiologic effect Effects 0.000 description 1
- 239000000203 mixture Substances 0.000 description 1
- 238000012544 monitoring process Methods 0.000 description 1
- 239000002114 nanocomposite Substances 0.000 description 1
- 239000003129 oil well Substances 0.000 description 1
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- 229910052760 oxygen Inorganic materials 0.000 description 1
- 239000001301 oxygen Substances 0.000 description 1
- 239000004033 plastic Substances 0.000 description 1
- 229920003023 plastic Polymers 0.000 description 1
- 229920002451 polyvinyl alcohol Polymers 0.000 description 1
- 230000000750 progressive effect Effects 0.000 description 1
- 229920005604 random copolymer Polymers 0.000 description 1
- 238000011084 recovery Methods 0.000 description 1
- 230000002787 reinforcement Effects 0.000 description 1
- 238000011160 research Methods 0.000 description 1
- 150000003839 salts Chemical class 0.000 description 1
- 238000004513 sizing Methods 0.000 description 1
- 229920001169 thermoplastic Polymers 0.000 description 1
- 229920002397 thermoplastic olefin Polymers 0.000 description 1
- 239000004416 thermosoftening plastic Substances 0.000 description 1
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 description 1
Images
Classifications
-
- F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
- F16—ENGINEERING ELEMENTS AND UNITS; GENERAL MEASURES FOR PRODUCING AND MAINTAINING EFFECTIVE FUNCTIONING OF MACHINES OR INSTALLATIONS; THERMAL INSULATION IN GENERAL
- F16L—PIPES; JOINTS OR FITTINGS FOR PIPES; SUPPORTS FOR PIPES, CABLES OR PROTECTIVE TUBING; MEANS FOR THERMAL INSULATION IN GENERAL
- F16L15/00—Screw-threaded joints; Forms of screw-threads for such joints
- F16L15/001—Screw-threaded joints; Forms of screw-threads for such joints with conical threads
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B17/00—Drilling rods or pipes; Flexible drill strings; Kellies; Drill collars; Sucker rods; Cables; Casings; Tubings
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B17/00—Drilling rods or pipes; Flexible drill strings; Kellies; Drill collars; Sucker rods; Cables; Casings; Tubings
- E21B17/10—Wear protectors; Centralising devices, e.g. stabilisers
- E21B17/1007—Wear protectors; Centralising devices, e.g. stabilisers for the internal surface of a pipe, e.g. wear bushings for underwater well-heads
Definitions
- Tubular goods such as oil country tubular goods (“OCTG's”) (e.g., well casing, tubing, drillpipe, drill collars, and line pipe) and flowline tubular goods, are often used for transportation of gases, liquids, and mechanical equipment, including various applications related to extraction of petroleum and natural gas from underground reservoirs, transportation of petroleum, natural gas, and other materials, such as solution mining and slurry transport lines in the mining industry.
- OCTG's oil country tubular goods
- flowline tubular goods are often used for transportation of gases, liquids, and mechanical equipment, including various applications related to extraction of petroleum and natural gas from underground reservoirs, transportation of petroleum, natural gas, and other materials, such as solution mining and slurry transport lines in the mining industry.
- OCTG's may be used to transport the product from the underground reservoir, and also to house mechanical equipment (e.g., artificial lift devices, rod couplings, plungers, reciprocating rod pumping units, rotating progressive cavity pumps, and plunger lift units), electrical equipment (e.g., well monitoring equipment), and/or transport gases or liquids for disposal operations or secondary removal operations.
- gases and liquids may contain corrosive materials such as, by way of example only, salt water, dissolved oxygen, CO 2 , or H 2 S.
- flowline tubular goods may be used to transport petroleum, petroleum products, natural gas, or other gases or liquids from one point to another.
- the gases and liquids which flow within flowlines may, comprise corrosive and/or abrasive components.
- flowline tubular goods may also occasionally require the use of mechanical equipment, such as pigs, to clean or service the tubular good.
- tubular goods which decrease or eliminate the mechanical and/or chemical wear, fatigue, or failure caused by the conditions surrounding the extraction of materials such as petroleum or natural gas and transportation of materials, thereby potentially increasing the life and productivity of the tubular good.
- the methods comprise disposing a liner along at least a portion of the tubular good.
- the liner may decrease friction, thereby decreasing mechanical wear as well as reducing the amount of energy necessary to operate the mechanical tool or pump the abrasive fluid.
- the liner may also comprise a material which is resistant to particular chemicals or a barrier to particular chemicals, thereby decreasing or eliminating contact between the chemicals and the tubular good and decreasing or eliminating the wear or corrosion caused by those chemicals.
- FIG. 1 is a schematic drawing of a tubular good in accordance with embodiments of the present invention.
- FIG. 2 is a cross section of a tubular good in accordance with embodiments of the present invention.
- FIG. 1 there is shown metal tubing 30 , coupling 36 , and liner 40 .
- Two joints of metal tubing 30 having an inner diameter 32 and outer diameter 34 , are connected together by coupling 36 .
- a liner 40 Disposed within each tubing joint 30 adjacent to its inner surface 38 is a liner 40 (an embodiment of which is shown in detail in FIG. 2).
- Liner 40 may be a multilayer system comprising both a wear resistant material and a diffusion barrier. In some embodiments, where gas diffusion is of minimal or no concern, liner 40 may comprise a layer comprising only a wear barrier such as polypropylene with no diffusion barrier being present.
- the liner 40 may be disposed within the tubing 30 by any one of several methods known in the art.
- One method of disposing the liner within the tubing bore is to provide a polymer liner having an outside diameter which is slightly greater than or equal to the inner diameter of the tubing section pipe having an outside diameter larger than the internal diameter of the tubing. Reduce the outside of the liner and insert the reduced diameter liner within the tubing. After the liner is in place, it will attempt to substantially return to its original shape and will become secured within the tubing section via process called plastic deformation. There may be numerous methods of reducing the outside diameter of the liner for insertion into a tubing section are available.
- rollers may be used to mechanically reduce the outside diameter of the liner by the desired amount and to push the liner into the tubing joint.
- Other methods include pulling the liner through a sizing sleeve or orifice and pushing the reduced diameter liner into place in the tubing.
- One method of disposing the polymer liners within the tubing sections includes providing a liner having an initial outside diameter similar to or larger than the inner diameter of the tubing, reducing the outer diameter of the liner by mechanical means and inserting the liner into the tubing bore.
- the ends of the polymer liner may then be softened using a heat source and formed around the end of the external pipe thread on the metal pipe. In some cases, the ends may be reinforced for additional structural integrity.
- the ends may then be joined onto a coupling (with or without an internal coating or corrosion resistant insert) used to join each stick of lined pipe. The process ultimately provides a one-piece seamless liner in each joint that is mechanically bonded to the metal pipe ID.
- the wall thickness of the claimed liners is preferably between about 2 and 10 millimeters.
- the diameter of the claimed liners may be between about 20 and 700 millimeters or greater. In the embodiments shown in FIG. 1, the thickness “t” of the liner 40 is about 4 millimeters.
- lined tubular good 100 comprising outer layer 110 , diffusion barrier 120 , adhesive layers 130 and 160 (optional), and friction and wear reducing layers 140 and 150 outer layer 110 may be a metal tubular good such as an OCTG, a flowline tubular good, or a solution mining or slurry transport line.
- the tubular good liner is preferably comprised of elements 120 , 130 , 140 , 150 , and 160 .
- Friction and wear reducing layers 140 and 150 may comprise, by way of example only, polyethylene or polypropylene. Layers 140 and 150 may or may not consist of the same material.
- Diffusion reducing layer may comprise, by way of example only, a vinyl alcohol such as polyvinyl alcohol.
- Layer 140 may be bonded to diffusion barrier 120 by any method as would be appreciated by one of skill in the art.
- layers 120 and 140 may be bonded by adhesive layer 130 and layers 150 and 120 may be bonded by adhesive layer 160 .
- Adhesive layers 130 and 160 may be, but are not necessarily, the same adhesive.
- Adhesive layers 130 and 160 may comprise, any acceptable polymer adhesive as is known in the art, such as copolymers.
- layers 120 and 140 may be bonded by the addition of additives to the layers, by way of example only, 2,5-furandione, the chemical structure of which is set forth as Formula 1 below:
- the layers are typically coextruded through a specially designed extrusion die head using multiple extruders.
- the melted polymer layers are then cooled into one continuous seemless tube.
- the friction and wear reducing layer may comprise nucleated polypropylene; polyolefins containing nanocomposites or other additives to control diffusion rates; impact copolymer grade polypropylene; homopolymer grade polypropylene; heterophasic copolymers; fractional melt grade polypropylene; other thermoplastics coextruded with polypropylene; reactor made thermoplastic polyolefins; metallocene catalyzed polypropylenes; random copolymer polypropylenes; blends, alloys, filled or reinforced polypropylene or polyethylene containing other polyolefins and structural reinforcement.
- additives may be included in the polymer to increase the lubricity of the liner material and decrease the coefficient of friction of the product.
- the gas diffusion barrier may comprise other polymers, organic or inorganic materials, or metals. In some embodiments, this barrier is chosen to reduce or eliminate the permeation of carbon dioxide through liners utilized in CO 2 floods and WAG (water-alternating-gas) injection systems for oil production enhanced recovery operations.
- CO 2 floods and WAG water-alternating-gas
- the friction wear reducing layer and the diffusion barrier are chemically bonded 2,5-furandione or other similar additives.
- the layers may also be bound by any acceptable adhesive as is known in the art.
- an acceptable adhesive may comprise a copolymer.
- the friction wear reducing layer and the diffusion barrier need not be directly bonded together. There may be intermediate layers between the two. Additionally, there may be layers radially outward or inward of the diffusion barrier.
- the diffusion barrier may be sandwiched between the friction and wear reducing layer and a third layer. The third layer may be of the same or different material as the friction and wear reducing layer.
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- Engineering & Computer Science (AREA)
- Mining & Mineral Resources (AREA)
- Geology (AREA)
- Life Sciences & Earth Sciences (AREA)
- Mechanical Engineering (AREA)
- Fluid Mechanics (AREA)
- Environmental & Geological Engineering (AREA)
- Physics & Mathematics (AREA)
- General Engineering & Computer Science (AREA)
- General Life Sciences & Earth Sciences (AREA)
- Geochemistry & Mineralogy (AREA)
- Rigid Pipes And Flexible Pipes (AREA)
- Laminated Bodies (AREA)
- Application Of Or Painting With Fluid Materials (AREA)
Abstract
Disclosed herein are tubular goods and tubular good liners which decrease or eliminate friction and mechanical wear and decrease or eliminate chemical corrosion to the walls of the tubular good. The liners may include a diffusion barrier, an adhesive, and a friction and wear resistant layer.
Description
- This application claims priority to U.S. Provisional Patent Application Serial No. 60/367,132, filed May 16, 2002, incorporated herein by reference.
- Not Applicable
- Tubular goods, such as oil country tubular goods (“OCTG's”) (e.g., well casing, tubing, drillpipe, drill collars, and line pipe) and flowline tubular goods, are often used for transportation of gases, liquids, and mechanical equipment, including various applications related to extraction of petroleum and natural gas from underground reservoirs, transportation of petroleum, natural gas, and other materials, such as solution mining and slurry transport lines in the mining industry. OCTG's may be used to transport the product from the underground reservoir, and also to house mechanical equipment (e.g., artificial lift devices, rod couplings, plungers, reciprocating rod pumping units, rotating progressive cavity pumps, and plunger lift units), electrical equipment (e.g., well monitoring equipment), and/or transport gases or liquids for disposal operations or secondary removal operations. These gases and liquids may contain corrosive materials such as, by way of example only, salt water, dissolved oxygen, CO2, or H2S. In addition, flowline tubular goods may be used to transport petroleum, petroleum products, natural gas, or other gases or liquids from one point to another. The gases and liquids which flow within flowlines may, comprise corrosive and/or abrasive components. In addition, flowline tubular goods may also occasionally require the use of mechanical equipment, such as pigs, to clean or service the tubular good.
- With respect to moving mechanical equipment and abrasive fluids, such as reciprocating or rotating rods or pumps or drilling or mining slurries (e.g., drilling mud), friction and abrasion may cause wear, fatigue, and even failure of the pipe and/or the equipment. In addition, this wear, fatigue, or failure may be accelerated due to the presence of corrosive or abrasive materials, such as, for example CO2, or by deviations in the direction of the well bore. One method of combatting this wear in oil well production equipment is disclosed in U.S. Patent No. RE36,362 to Jackson, incorporated herein by reference.
- In addition to the possible acceleration of mechanical wear, fatigue, and failure, the presence of corrosive material, in and of itself, may cause chemical damage to the OCTG's and flowline tubular goods. By way of example only, the presence of CO2, when contacted with metal or other materials may cause corrosion, dusting, rusting, or pitting, which may lead to failure of the material. In addition, the presence of microbiological active agents, such as bacteria, may produce chemicals which influence or accelerate corrosion.
- It would therefore be desirable to create tubular goods which decrease or eliminate the mechanical and/or chemical wear, fatigue, or failure caused by the conditions surrounding the extraction of materials such as petroleum or natural gas and transportation of materials, thereby potentially increasing the life and productivity of the tubular good.
- Disclosed herein are methods and apparatus for reducing or eliminating the mechanical and/or chemical wear, fatigue, and failure on tubular goods. The methods comprise disposing a liner along at least a portion of the tubular good. The liner may decrease friction, thereby decreasing mechanical wear as well as reducing the amount of energy necessary to operate the mechanical tool or pump the abrasive fluid. In addition, the liner may also comprise a material which is resistant to particular chemicals or a barrier to particular chemicals, thereby decreasing or eliminating contact between the chemicals and the tubular good and decreasing or eliminating the wear or corrosion caused by those chemicals.
- FIG. 1 is a schematic drawing of a tubular good in accordance with embodiments of the present invention.
- FIG. 2 is a cross section of a tubular good in accordance with embodiments of the present invention.
- Referring now to FIG. 1, there is shown
metal tubing 30,coupling 36, andliner 40. Two joints ofmetal tubing 30, having aninner diameter 32 andouter diameter 34, are connected together bycoupling 36. Disposed within eachtubing joint 30 adjacent to itsinner surface 38 is a liner 40 (an embodiment of which is shown in detail in FIG. 2).Liner 40 may be a multilayer system comprising both a wear resistant material and a diffusion barrier. In some embodiments, where gas diffusion is of minimal or no concern,liner 40 may comprise a layer comprising only a wear barrier such as polypropylene with no diffusion barrier being present. - The
liner 40 may be disposed within thetubing 30 by any one of several methods known in the art. One method of disposing the liner within the tubing bore is to provide a polymer liner having an outside diameter which is slightly greater than or equal to the inner diameter of the tubing section pipe having an outside diameter larger than the internal diameter of the tubing. Reduce the outside of the liner and insert the reduced diameter liner within the tubing. After the liner is in place, it will attempt to substantially return to its original shape and will become secured within the tubing section via process called plastic deformation. There may be numerous methods of reducing the outside diameter of the liner for insertion into a tubing section are available. For example, rollers may be used to mechanically reduce the outside diameter of the liner by the desired amount and to push the liner into the tubing joint. Other methods include pulling the liner through a sizing sleeve or orifice and pushing the reduced diameter liner into place in the tubing. - One method of disposing the polymer liners within the tubing sections includes providing a liner having an initial outside diameter similar to or larger than the inner diameter of the tubing, reducing the outer diameter of the liner by mechanical means and inserting the liner into the tubing bore. The ends of the polymer liner may then be softened using a heat source and formed around the end of the external pipe thread on the metal pipe. In some cases, the ends may be reinforced for additional structural integrity. The ends may then be joined onto a coupling (with or without an internal coating or corrosion resistant insert) used to join each stick of lined pipe. The process ultimately provides a one-piece seamless liner in each joint that is mechanically bonded to the metal pipe ID. The wall thickness of the claimed liners is preferably between about 2 and 10 millimeters. The diameter of the claimed liners may be between about 20 and 700 millimeters or greater. In the embodiments shown in FIG. 1, the thickness “t” of the
liner 40 is about 4 millimeters. - Referring now to FIG. 2 (not to scale), there is shown lined tubular good100 comprising
outer layer 110,diffusion barrier 120,adhesive layers 130 and 160 (optional), and friction and wear reducinglayers outer layer 110 may be a metal tubular good such as an OCTG, a flowline tubular good, or a solution mining or slurry transport line. The tubular good liner is preferably comprised ofelements wear reducing layers Layers Layer 140 may be bonded todiffusion barrier 120 by any method as would be appreciated by one of skill in the art. By way of example only,layers adhesive layer 130 andlayers adhesive layer 160.Adhesive layers Adhesive layers -
- when added to the layers may cause the layers to become bonded together without the need for additional adhesives.
- The layers are typically coextruded through a specially designed extrusion die head using multiple extruders. The melted polymer layers are then cooled into one continuous seemless tube.
- While embodiments of the invention have been described herein, it will be recognized and understood that various modifications may be made and the appended claims are intended to cover all such modifications which may fall within the spirit and scope of the invention. By way of example only, the friction and wear reducing layer may comprise nucleated polypropylene; polyolefins containing nanocomposites or other additives to control diffusion rates; impact copolymer grade polypropylene; homopolymer grade polypropylene; heterophasic copolymers; fractional melt grade polypropylene; other thermoplastics coextruded with polypropylene; reactor made thermoplastic polyolefins; metallocene catalyzed polypropylenes; random copolymer polypropylenes; blends, alloys, filled or reinforced polypropylene or polyethylene containing other polyolefins and structural reinforcement. In addition, additives may be included in the polymer to increase the lubricity of the liner material and decrease the coefficient of friction of the product.
- The gas diffusion barrier may comprise other polymers, organic or inorganic materials, or metals. In some embodiments, this barrier is chosen to reduce or eliminate the permeation of carbon dioxide through liners utilized in CO2 floods and WAG (water-alternating-gas) injection systems for oil production enhanced recovery operations.
- In embodiments in which the friction wear reducing layer and the diffusion barrier are chemically bonded 2,5-furandione or other similar additives may be used. The layers may also be bound by any acceptable adhesive as is known in the art. For example, an acceptable adhesive may comprise a copolymer. It is also envisioned that the friction wear reducing layer and the diffusion barrier need not be directly bonded together. There may be intermediate layers between the two. Additionally, there may be layers radially outward or inward of the diffusion barrier. By way of example only, the diffusion barrier may be sandwiched between the friction and wear reducing layer and a third layer. The third layer may be of the same or different material as the friction and wear reducing layer.
Claims (42)
1. A tubular good comprising:
an outer pipe layer; and
an inner layer, wherein the inner layer comprises a diffusion barrier and a friction reducing layer, and wherein the diffusion barrier is disposed radially outward of the friction reducing layer.
2. The tubular good of claim 1 further comprising an adhesive layer disposed between the diffusion barrier and the friction reducing layer.
3. The tubular good of claim 1 wherein the tubular good is an oil country tubular good.
4. The tubular good of claim 1 wherein the tubular good is a flowline tubular good.
5. The tubular good of claim 1 wherein the diffusion barrier comprises a vinyl alcohol.
6. The tubular good of claim 1 wherein the friction reducing layer comprises a polyolefin.
8. The tubular good of claim 1 wherein the friction reducing layer comprises polyethylene.
9. The tubing good of claim 1 wherein the friction reducing layer comprises a homopolymer.
10. The tubing good of claim 1 wherein the friction reducing layer comprises a copolymer.
11. The tubing good of claim 1 wherein the friction reducing layer comprises polypropylene.
12. The tubing good of claim 1 further comprising a third layer radially outward from the diffusion barrier and radially inward from the outer pipe layer.
13. A method of preparing a tubular good, the method comprising:
providing an outer tubular layer;
providing an inner tubular layer;
wherein the inner tubular layer comprises a chemical barrier and a wear reducing layer;
wherein the chemical barrier is disposed radially outward from the wear reducing layer;
inserting the inner tubular layer into the outer tubular layer.
14. The method of claim 13 further comprising bonding the chemical barrier to the wear reducing layer.
15. The method of claim 13 further comprising providing an adhesive layer disposed between the chemical barrier and the wear reducing layer, wherein the adhesive layer bonds the chemical barrier to the wear reducing layer.
17. The method of claim 13 wherein the wear reducing layer comprises a polyolefin.
18. The method of claim 13 wherein the wear reducing layer comprises polyethylene.
19. The method of claim 13 wherein the diffusion barrier comprises a vinyl alcohol.
20. The method of claim 13 wherein the wear reducing layer comprises a copolymer.
21. The method of claim 13 wherein the wear reducing layer comprises polypropylene.
22. The method of claim 13 wherein the wear reducing layer comprises a homopolymer.
23. The method of claim 13 further comprising providing a third layer wherein the third layer is disposed radially outward from the diffusion barrier and radially inward from the outer tubular layer.
24. A tubular good liner comprising:
a wear barrier; and
a diffusion barrier;
wherein the diffusion barrier is disposed radially outside of the wear barrier; and
wherein the diffusion barrier is bonded to the wear barrier.
25. The tubular good of claim 24 further comprising an adhesive layer bonding the wear barrier to the diffusion barrier.
27. The tubular good liner of claim 24 wherein the wear barrier comprises polyethylene.
28. The tubular good liner of claim 24 wherein the wear barrier comprises polypropylene.
29. The tubular good liner of claim 24 wherein the diffusion barrier comprises a vinyl alcohol.
30. The tubular good liner of claim 24 wherein the wear barrier comprises a homopolymer.
31. The tubular good liner of claim 24 wherein the wear barrier comprises a copolymer.
32. The tubular liner of claim 24 further comprising a third layer disposed radially outward from the diffusion barrier.
33. A tubular good liner comprising:
a means for reducing friction;
a means for preventing diffusion of a compound; and
a means for bonding the means for reducing to the means for preventing;
wherein the means for preventing is disposed radially outward from the means for reducing.
34. A tubular good liner comprising polypropylene.
35. The tubular good liner of claim 34 wherein the tubular good is an oil country tubular good.
36. The tubular good liner of claim 34 wherein the tubular good is a flowline tubular good.
37. The tubular good liner of claim 34 wherein the tubular good is a slurry transport line.
38. The tubular good liner of claim 34 wherein the tubular good is a solution mining tubular good.
39. The tubular good liner of claim 34 wherein the tubular good houses a reciprocating member.
40. The tubular good liner of claim 34 wherein the tubular good contains a rotating member.
41. The tubular good liner of claim 34 wherein the tubular good transports abrasive material.
42. A method for producing well fluids:
providing a rod pumping system comprising at least one sucker rod disposed within a string of tubing which extends into said well, the string of tubing comprising at least one tubing section having a bore and an inside diameter; a down hole pump operably connected to the at least one sucker rod; and means for reciprocating the at least one sucker rod;
wherein a liner comprising polypropylene is disposed within the bore of the tubing to eliminate or reduce contact between the at least one sucker rod and the tubing string.
Priority Applications (2)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
US10/366,936 US20030213596A1 (en) | 2002-05-16 | 2003-02-14 | Tubular goods and liners |
US11/343,690 US7740077B2 (en) | 2002-05-16 | 2006-01-31 | Downhole oilfield tubulars |
Applications Claiming Priority (2)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
US36713202P | 2002-05-16 | 2002-05-16 | |
US10/366,936 US20030213596A1 (en) | 2002-05-16 | 2003-02-14 | Tubular goods and liners |
Related Child Applications (1)
Application Number | Title | Priority Date | Filing Date |
---|---|---|---|
US11/343,690 Continuation-In-Part US7740077B2 (en) | 2002-05-16 | 2006-01-31 | Downhole oilfield tubulars |
Publications (1)
Publication Number | Publication Date |
---|---|
US20030213596A1 true US20030213596A1 (en) | 2003-11-20 |
Family
ID=29549879
Family Applications (1)
Application Number | Title | Priority Date | Filing Date |
---|---|---|---|
US10/366,936 Abandoned US20030213596A1 (en) | 2002-05-16 | 2003-02-14 | Tubular goods and liners |
Country Status (5)
Country | Link |
---|---|
US (1) | US20030213596A1 (en) |
AU (1) | AU2003223178A1 (en) |
BR (1) | BR0310065A (en) |
CA (1) | CA2486177C (en) |
WO (1) | WO2003098087A1 (en) |
Cited By (14)
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---|---|---|---|---|
US20050194718A1 (en) * | 2004-02-17 | 2005-09-08 | Blades David J. | Pipe liners and method of lining pipes |
US20080173396A1 (en) * | 2007-01-18 | 2008-07-24 | Lubrizol Advanced Materials, Inc. | Cured In Place Pipe Liner |
WO2008138957A2 (en) * | 2007-05-15 | 2008-11-20 | Shell Internationale Research Maatschappij B.V. | System for drilling a wellbore |
US20110011482A1 (en) * | 2007-12-20 | 2011-01-20 | Omv Exploration And Production Gmbh | Well tubings with polymer liners |
US20140182946A1 (en) * | 2012-12-31 | 2014-07-03 | Longyear Tm, Inc. | Engineered materials for drill rod applications |
CN104213847A (en) * | 2013-06-05 | 2014-12-17 | 中国石油天然气股份有限公司 | Method for determining well landing section of oil well anti-eccentric lining oil pipe |
US8997880B2 (en) | 2012-01-31 | 2015-04-07 | Wagon Trail Ventures, Inc. | Lined downhole oilfield tubulars |
CN105299320A (en) * | 2015-11-27 | 2016-02-03 | 哈尔滨商业大学 | Quakeproof petroleum pipeline with high stability and convenient for petroleum dredging |
CN106593361A (en) * | 2017-01-18 | 2017-04-26 | 大庆市华禹石油机械制造有限公司 | Intelligent driving device for oil-well pump and winding type pumping unit system |
CN109798075A (en) * | 2019-02-10 | 2019-05-24 | 北京工商大学 | A kind of endurance multilayered structure steel oil pumping polish rod and its processing technology |
GB2588641A (en) * | 2019-10-30 | 2021-05-05 | Barnes Stephen | Improved pipe liner and associated methods |
CN113685618A (en) * | 2021-08-18 | 2021-11-23 | 江苏洁润管业有限公司 | High-pressure oil pipeline and preparation device thereof |
US20220381102A1 (en) * | 2019-11-13 | 2022-12-01 | SPEX Group Holdings Limited | Improved tool |
CN117363026A (en) * | 2023-12-05 | 2024-01-09 | 上海贝思特管业有限公司 | Nano modified polyethylene plastic pipe for underground communication pipeline and preparation method thereof |
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DE102017117868A1 (en) * | 2017-08-07 | 2019-02-07 | Benteler Steel/Tube Gmbh | Pipe element and method for fixing such a pipe element in a tubular opening |
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- 2003-02-14 AU AU2003223178A patent/AU2003223178A1/en not_active Abandoned
- 2003-02-14 WO PCT/US2003/004493 patent/WO2003098087A1/en not_active Application Discontinuation
- 2003-02-14 US US10/366,936 patent/US20030213596A1/en not_active Abandoned
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US5069284A (en) * | 1990-11-14 | 1991-12-03 | Joe C. McQueen, Jr. | Wear resistant rod guide |
US5472754A (en) * | 1993-02-05 | 1995-12-05 | Nobel Plastiques | Multilayer plastics material hose |
US6079959A (en) * | 1996-07-15 | 2000-06-27 | Saint-Gobain Performance Plastics Corporation | Reciprocating pump |
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US6422269B1 (en) * | 1998-03-23 | 2002-07-23 | Wirsbo Bruks Ab | Multilayer plastic pipe and its use |
US6170535B1 (en) * | 1998-11-17 | 2001-01-09 | Salflex Polymers Ltd. | Multi-layer conduit |
US6177516B1 (en) * | 1999-09-28 | 2001-01-23 | Equistar Chemincals, Lp | Adhesives and composite structures formed therewith |
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Cited By (22)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US20050194718A1 (en) * | 2004-02-17 | 2005-09-08 | Blades David J. | Pipe liners and method of lining pipes |
US20080173396A1 (en) * | 2007-01-18 | 2008-07-24 | Lubrizol Advanced Materials, Inc. | Cured In Place Pipe Liner |
US8047238B2 (en) | 2007-01-18 | 2011-11-01 | Lubrizol Advanced Materials, Inc. | Cured in place pipe liner |
US8636869B2 (en) | 2007-01-18 | 2014-01-28 | Lubrizol Advanced Materials, Inc. | Cured in place pipe liner |
WO2008138957A2 (en) * | 2007-05-15 | 2008-11-20 | Shell Internationale Research Maatschappij B.V. | System for drilling a wellbore |
WO2008138957A3 (en) * | 2007-05-15 | 2009-01-15 | Shell Int Research | System for drilling a wellbore |
GB2461471A (en) * | 2007-05-15 | 2010-01-06 | Shell Int Research | System for drilling a wellbore |
GB2461471B (en) * | 2007-05-15 | 2012-02-15 | Shell Int Research | System for drilling a wellbore |
US9371702B2 (en) * | 2007-12-20 | 2016-06-21 | Borealis Ag | Well tubings with polymer liners |
US20110011482A1 (en) * | 2007-12-20 | 2011-01-20 | Omv Exploration And Production Gmbh | Well tubings with polymer liners |
US8997880B2 (en) | 2012-01-31 | 2015-04-07 | Wagon Trail Ventures, Inc. | Lined downhole oilfield tubulars |
US20140182946A1 (en) * | 2012-12-31 | 2014-07-03 | Longyear Tm, Inc. | Engineered materials for drill rod applications |
CN104213847A (en) * | 2013-06-05 | 2014-12-17 | 中国石油天然气股份有限公司 | Method for determining well landing section of oil well anti-eccentric lining oil pipe |
CN105299320A (en) * | 2015-11-27 | 2016-02-03 | 哈尔滨商业大学 | Quakeproof petroleum pipeline with high stability and convenient for petroleum dredging |
CN106593361A (en) * | 2017-01-18 | 2017-04-26 | 大庆市华禹石油机械制造有限公司 | Intelligent driving device for oil-well pump and winding type pumping unit system |
CN109798075A (en) * | 2019-02-10 | 2019-05-24 | 北京工商大学 | A kind of endurance multilayered structure steel oil pumping polish rod and its processing technology |
GB2588641A (en) * | 2019-10-30 | 2021-05-05 | Barnes Stephen | Improved pipe liner and associated methods |
GB2588641B (en) * | 2019-10-30 | 2022-04-20 | Flowlining Ltd | Improved pipe liner and associated methods |
US11796091B2 (en) | 2019-10-30 | 2023-10-24 | Flowlining Limited | Pipe liner and associated methods |
US20220381102A1 (en) * | 2019-11-13 | 2022-12-01 | SPEX Group Holdings Limited | Improved tool |
CN113685618A (en) * | 2021-08-18 | 2021-11-23 | 江苏洁润管业有限公司 | High-pressure oil pipeline and preparation device thereof |
CN117363026A (en) * | 2023-12-05 | 2024-01-09 | 上海贝思特管业有限公司 | Nano modified polyethylene plastic pipe for underground communication pipeline and preparation method thereof |
Also Published As
Publication number | Publication date |
---|---|
CA2486177C (en) | 2010-11-23 |
BR0310065A (en) | 2005-03-01 |
AU2003223178A1 (en) | 2003-12-02 |
CA2486177A1 (en) | 2003-11-27 |
WO2003098087A1 (en) | 2003-11-27 |
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Legal Events
Date | Code | Title | Description |
---|---|---|---|
AS | Assignment |
Owner name: WAGON TRAIL VENTURES, INC., TEXAS Free format text: ASSIGNMENT OF ASSIGNORS INTEREST;ASSIGNOR:DAVIS, ROBERT H.;REEL/FRAME:014103/0208 Effective date: 20030515 |
|
STCB | Information on status: application discontinuation |
Free format text: ABANDONED -- FAILURE TO RESPOND TO AN OFFICE ACTION |