CA2486177C - Tubular goods and liners - Google Patents
Tubular goods and liners Download PDFInfo
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- CA2486177C CA2486177C CA2486177A CA2486177A CA2486177C CA 2486177 C CA2486177 C CA 2486177C CA 2486177 A CA2486177 A CA 2486177A CA 2486177 A CA2486177 A CA 2486177A CA 2486177 C CA2486177 C CA 2486177C
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- Prior art keywords
- liner
- layer
- tubing
- layers
- metal tubular
- Prior art date
- Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
- Expired - Lifetime
Links
- 239000010410 layer Substances 0.000 claims abstract description 46
- 238000000034 method Methods 0.000 claims description 23
- -1 polypropylene Polymers 0.000 claims description 15
- 229910052751 metal Inorganic materials 0.000 claims description 14
- 239000002184 metal Substances 0.000 claims description 14
- 239000004743 Polypropylene Substances 0.000 claims description 13
- 229920001155 polypropylene Polymers 0.000 claims description 13
- 239000000654 additive Substances 0.000 claims description 5
- 230000008878 coupling Effects 0.000 claims description 5
- 238000010168 coupling process Methods 0.000 claims description 5
- 238000005859 coupling reaction Methods 0.000 claims description 5
- 239000012530 fluid Substances 0.000 claims description 4
- 238000004519 manufacturing process Methods 0.000 claims description 3
- 238000005086 pumping Methods 0.000 claims description 3
- 230000000750 progressive effect Effects 0.000 claims description 2
- 229920005629 polypropylene homopolymer Polymers 0.000 claims 6
- 239000002356 single layer Substances 0.000 claims 2
- 230000000996 additive effect Effects 0.000 claims 1
- 230000015572 biosynthetic process Effects 0.000 claims 1
- 230000004888 barrier function Effects 0.000 abstract description 13
- 238000009792 diffusion process Methods 0.000 abstract description 13
- 239000000126 substance Substances 0.000 abstract description 10
- 239000012790 adhesive layer Substances 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
- 229920000642 polymer Polymers 0.000 description 7
- 239000000853 adhesive Substances 0.000 description 5
- 230000001070 adhesive effect Effects 0.000 description 5
- 229910002092 carbon dioxide Inorganic materials 0.000 description 5
- 239000007788 liquid Substances 0.000 description 5
- CURLTUGMZLYLDI-UHFFFAOYSA-N Carbon dioxide Chemical compound O=C=O CURLTUGMZLYLDI-UHFFFAOYSA-N 0.000 description 4
- 229920001577 copolymer Polymers 0.000 description 4
- 238000005065 mining 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
- 239000002002 slurry Substances 0.000 description 3
- 239000004698 Polyethylene Substances 0.000 description 2
- 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
- 229920000573 polyethylene Polymers 0.000 description 2
- 229920000098 polyolefin Polymers 0.000 description 2
- 239000000243 solution Substances 0.000 description 2
- 241000894006 Bacteria Species 0.000 description 1
- IMROMDMJAWUWLK-UHFFFAOYSA-N Ethenol Chemical compound OC=C IMROMDMJAWUWLK-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
- 239000003082 abrasive agent Substances 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
- 229920001519 homopolymer Polymers 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
- 239000011368 organic material Substances 0.000 description 1
- 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
- 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
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
Landscapes
- 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
Tubular goods and tubular good liners which decrease or eliminate friction and mechanicial wear and decrease or eliminate chemical corrosion to the walls of the tubular good. The tubular good (100) comprises outer layer (110), diffusion barrier (120), adhesive layers (130) and optionally (160), and friction and wear reducing layers (140, 150). The tubular liner is comprised of elements (120, 130, 140, 150 and 160).
Description
TUBULAR GOODS AND LINERS
STATEMENT REGARDING FEDERALLY SPONSORED RESEARCH
Not Applicable BACKGROUND
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, C02, 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 C02, 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.
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 C02, 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.
SUMMARY
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.
BRIEF DESCRIPTION OF THE DRAWINGS
Figure 1 is a schematic drawing of a tubular good in accordance with embodiments of the present invention.
Figure 2 is a cross section of a tubular good in accordance with embodiments of the present invention.
DETAILED DESCRIPTION
Referring now to Figure 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. 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 Figure 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. 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 Figure 2 (not to scale), there is shown lined tubular good 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. By way of example only, 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.
STATEMENT REGARDING FEDERALLY SPONSORED RESEARCH
Not Applicable BACKGROUND
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, C02, 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 C02, 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.
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 C02, 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.
SUMMARY
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.
BRIEF DESCRIPTION OF THE DRAWINGS
Figure 1 is a schematic drawing of a tubular good in accordance with embodiments of the present invention.
Figure 2 is a cross section of a tubular good in accordance with embodiments of the present invention.
DETAILED DESCRIPTION
Referring now to Figure 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. 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 Figure 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. 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 Figure 2 (not to scale), there is shown lined tubular good 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. By way of example only, 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.
In addition, 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:
O O O (1), 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.
O O O (1), 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 (11)
1. A method of completing a well for production of fluids from an underground formation, which method comprises: installing within the wellbore an artificial lift apparatus and a string of tubing, wherein:
(a) the string of tubing includes a rigid metal tubular member having (i) a protruding end, (ii) a metallic outer surface that includes external threads and (iii) a metallic inner surface, wherein the string of tubing further includes a coupling that has internal threads that screw onto the external threads on the metallic outer surface and couple the rigid metal tubular member with another rigid metal tubular member;
(b) the metallic inner surface of the rigid metal tubular member defines a metal tubular borehole;
(c) a liner is disposed inside the metal tubular borehole adjacent to and against the metallic inner surface;
(d) the liner has a liner end and comprises one or more layers;
(e) at least one of the layers of the liner includes a polypropylene homopolymer; and (f) the liner end has been softened using a heat source and formed while in a softened condition around the protruding end of the rigid metal tubular member.
(a) the string of tubing includes a rigid metal tubular member having (i) a protruding end, (ii) a metallic outer surface that includes external threads and (iii) a metallic inner surface, wherein the string of tubing further includes a coupling that has internal threads that screw onto the external threads on the metallic outer surface and couple the rigid metal tubular member with another rigid metal tubular member;
(b) the metallic inner surface of the rigid metal tubular member defines a metal tubular borehole;
(c) a liner is disposed inside the metal tubular borehole adjacent to and against the metallic inner surface;
(d) the liner has a liner end and comprises one or more layers;
(e) at least one of the layers of the liner includes a polypropylene homopolymer; and (f) the liner end has been softened using a heat source and formed while in a softened condition around the protruding end of the rigid metal tubular member.
2. The method of claim 1 wherein the artificial lift apparatus includes a rod pumping system and a plurality of sucker rods disposed within a string of tubing that comprises a plurality of tubing sections each having a tubular borehole and an inside diameter; and a downhole pump operably connected to the sucker rods; wherein the one or more tubing sections has the liner comprising the polypropylene homopolymer disposed within the tubular borehole of the one or more tubing sections.
3. The method of claim 1, wherein operating an artificial lift apparatus includes operating a progressive cavity pumping system.
4. The method of claim 1, wherein the layer that includes the polypropylene homopolymer is in direct physical contact with the metallic inner surface, such that there is no other layer interposed between the metallic inner surface and the layer that includes the polypropylene homopolymer.
5. The method of claim 1, wherein the liner has an innermost layer which includes the polypropylene homopolymer such that any fluids being produced are capable of being in direct contact with the innermost layer of the liner.
6. The method of claim 1, wherein the liner has a single layer, and the single layer consists essentially of polypropylene.
7. The method of claim 1, where the liner has three or more layers and at least one of the layers includes polypropylene.
8. The method of claim 1, wherein the liner has three or more layers, including: a first outer layer, a second outer layer and an intermediate layer that is disposed between the first outer layer and the second outer layer, wherein the first outer layer or the second outer layer, or both, include polypropylene homopolymer, and wherein the intermediate layer contains no polypropylene.
9. The method of claim 1 wherein the liner includes up to 20% of an additive.
10. The method of claim 1 wherein the liner has a wall thickness between about 2 and 10 millimeters.
11. The method of claim 1 wherein the liner has a diameter between about 20 and 700 millimeters.
Priority Applications (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CA2714872A CA2714872C (en) | 2002-05-16 | 2003-02-14 | Downhole oilfield tubulars having liners with diffusion barrier layer |
Applications Claiming Priority (3)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| US36713202P | 2002-05-16 | 2002-05-16 | |
| US60/367,132 | 2002-05-16 | ||
| PCT/US2003/004493 WO2003098087A1 (en) | 2002-05-16 | 2003-02-14 | Tubular goods and liners |
Related Child Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| CA2714872A Division CA2714872C (en) | 2002-05-16 | 2003-02-14 | Downhole oilfield tubulars having liners with diffusion barrier layer |
Publications (2)
| Publication Number | Publication Date |
|---|---|
| CA2486177A1 CA2486177A1 (en) | 2003-11-27 |
| CA2486177C true CA2486177C (en) | 2010-11-23 |
Family
ID=29549879
Family Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| CA2486177A Expired - Lifetime CA2486177C (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) |
Families Citing this family (16)
| 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 |
| WO2008089167A1 (en) * | 2007-01-18 | 2008-07-24 | Lubrizol Advanced Materials, Inc. | Cured in place pipe liner |
| US20110272139A1 (en) * | 2007-05-15 | 2011-11-10 | Bernardus Johannes Henricus Van Den Brekel | System for drilling a wellbore |
| EA018661B1 (en) * | 2007-12-20 | 2013-09-30 | Бореалис Аг | 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 |
| CN104213847B (en) * | 2013-06-05 | 2016-08-10 | 中国石油天然气股份有限公司 | Method for determining well descending section of lining oil pipe for preventing deviation of oil well |
| CN105299320B (en) * | 2015-11-27 | 2018-02-16 | 哈尔滨商业大学 | High stability is easy to oil to dredge shockproof petroleum pipeline |
| CN106593361B (en) * | 2017-01-18 | 2017-11-03 | 华运隆腾机械制造有限公司 | A kind of oil well pump intelligent drive device and winding type pumping unit system |
| 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 |
| CN109798075B (en) * | 2019-02-10 | 2020-09-01 | 北京工商大学 | Fatigue-resistant steel oil pumping polished rod with multi-layer structure and processing technology thereof |
| GB2588641B (en) | 2019-10-30 | 2022-04-20 | Flowlining Ltd | Improved pipe liner and associated methods |
| GB2589313B (en) * | 2019-11-13 | 2022-05-18 | Spex Group Holdings Ltd | Improved tool |
| CN112377118B (en) * | 2020-11-12 | 2024-09-20 | 信达科创（唐山）石油设备有限公司 | Large-caliber coiled tubing and manufacturing process thereof |
| CN113685618B (en) * | 2021-08-18 | 2022-07-12 | 江苏洁润管业有限公司 | High-pressure oil pipeline and preparation device thereof |
| CN117363026B (en) * | 2023-12-05 | 2024-02-13 | 上海贝思特管业有限公司 | Nano modified polyethylene plastic pipe for underground communication pipeline and preparation method thereof |
Family Cites Families (11)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| USRE31016E (en) * | 1980-12-22 | 1982-08-24 | Conoco Inc. | Anti-friction sucker rod guide assembly |
| US4892442A (en) * | 1987-03-03 | 1990-01-09 | Dura-Line | Prelubricated innerduct |
| US5069284A (en) * | 1990-11-14 | 1991-12-03 | Joe C. McQueen, Jr. | Wear resistant rod guide |
| DK0635108T3 (en) * | 1993-02-05 | 1997-12-08 | Nobel Plastiques | Multilayer pipe system made of plastic material |
| US6079959A (en) * | 1996-07-15 | 2000-06-27 | Saint-Gobain Performance Plastics Corporation | Reciprocating pump |
| US6065537A (en) * | 1998-02-13 | 2000-05-23 | Flow Control Equipment, Inc. | Rod guide with both high erodible wear volume and by-pass area |
| SE511766C2 (en) * | 1998-03-23 | 1999-11-22 | Wirsbo Bruks Ab | Plastic multilayer tubes and their 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 |
| US20010029989A1 (en) * | 2000-02-17 | 2001-10-18 | Paz German N. | Pipeline identification and positioning system |
| DE20010111U1 (en) * | 2000-06-08 | 2001-10-31 | Wavin B.V., Zwolle | Multi-layer pipe |
-
2003
- 2003-02-14 CA CA2486177A patent/CA2486177C/en not_active Expired - Lifetime
- 2003-02-14 BR BR0310065-0A patent/BR0310065A/en not_active IP Right Cessation
- 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
- 2003-02-14 AU AU2003223178A patent/AU2003223178A1/en not_active Abandoned
Also Published As
| Publication number | Publication date |
|---|---|
| WO2003098087A1 (en) | 2003-11-27 |
| US20030213596A1 (en) | 2003-11-20 |
| BR0310065A (en) | 2005-03-01 |
| AU2003223178A1 (en) | 2003-12-02 |
| CA2486177A1 (en) | 2003-11-27 |
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Legal Events
| Date | Code | Title | Description |
|---|---|---|---|
| EEER | Examination request | ||
| MKEX | Expiry |
Effective date: 20230214 |