US20200263508A1 - Corrosion and abrasion resistant sucker rod - Google Patents
Corrosion and abrasion resistant sucker rod Download PDFInfo
- Publication number
- US20200263508A1 US20200263508A1 US16/276,658 US201916276658A US2020263508A1 US 20200263508 A1 US20200263508 A1 US 20200263508A1 US 201916276658 A US201916276658 A US 201916276658A US 2020263508 A1 US2020263508 A1 US 2020263508A1
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- United States
- Prior art keywords
- resistant layer
- sucker rod
- abrasion resistant
- corrosion resistant
- particulate material
- 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.)
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Classifications
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- 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
- E21B17/1071—Wear protectors; Centralising devices, e.g. stabilisers specially adapted for pump rods, e.g. sucker rods
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- C—CHEMISTRY; METALLURGY
- C23—COATING METALLIC MATERIAL; COATING MATERIAL WITH METALLIC MATERIAL; CHEMICAL SURFACE TREATMENT; DIFFUSION TREATMENT OF METALLIC MATERIAL; COATING BY VACUUM EVAPORATION, BY SPUTTERING, BY ION IMPLANTATION OR BY CHEMICAL VAPOUR DEPOSITION, IN GENERAL; INHIBITING CORROSION OF METALLIC MATERIAL OR INCRUSTATION IN GENERAL
- C23F—NON-MECHANICAL REMOVAL OF METALLIC MATERIAL FROM SURFACE; INHIBITING CORROSION OF METALLIC MATERIAL OR INCRUSTATION IN GENERAL; MULTI-STEP PROCESSES FOR SURFACE TREATMENT OF METALLIC MATERIAL INVOLVING AT LEAST ONE PROCESS PROVIDED FOR IN CLASS C23 AND AT LEAST ONE PROCESS COVERED BY SUBCLASS C21D OR C22F OR CLASS C25
- C23F11/00—Inhibiting corrosion of metallic material by applying inhibitors to the surface in danger of corrosion or adding them to the corrosive agent
- C23F11/08—Inhibiting corrosion of metallic material by applying inhibitors to the surface in danger of corrosion or adding them to the corrosive agent in other liquids
- C23F11/10—Inhibiting corrosion of metallic material by applying inhibitors to the surface in danger of corrosion or adding them to the corrosive agent in other liquids using organic inhibitors
- C23F11/173—Macromolecular compounds
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B17/00—Drilling rods or pipes; Flexible drill strings; Kellies; Drill collars; Sucker rods; Cables; Casings; Tubings
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- 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
- E21B17/1085—Wear protectors; Blast joints; Hard facing
-
- C—CHEMISTRY; METALLURGY
- C23—COATING METALLIC MATERIAL; COATING MATERIAL WITH METALLIC MATERIAL; CHEMICAL SURFACE TREATMENT; DIFFUSION TREATMENT OF METALLIC MATERIAL; COATING BY VACUUM EVAPORATION, BY SPUTTERING, BY ION IMPLANTATION OR BY CHEMICAL VAPOUR DEPOSITION, IN GENERAL; INHIBITING CORROSION OF METALLIC MATERIAL OR INCRUSTATION IN GENERAL
- C23C—COATING METALLIC MATERIAL; COATING MATERIAL WITH METALLIC MATERIAL; SURFACE TREATMENT OF METALLIC MATERIAL BY DIFFUSION INTO THE SURFACE, BY CHEMICAL CONVERSION OR SUBSTITUTION; COATING BY VACUUM EVAPORATION, BY SPUTTERING, BY ION IMPLANTATION OR BY CHEMICAL VAPOUR DEPOSITION, IN GENERAL
- C23C30/00—Coating with metallic material characterised only by the composition of the metallic material, i.e. not characterised by the coating process
- C23C30/005—Coating with metallic material characterised only by the composition of the metallic material, i.e. not characterised by the coating process on hard metal substrates
Definitions
- This disclosure relates generally to equipment utilized and operations performed in conjunction with a subterranean well and, in an example described below, more particularly provides a corrosion and abrasion resistant sucker rod.
- a sucker rod is typically used to transmit work from an actuator at surface to a downhole pump in a well.
- the actuator may reciprocate or rotate the sucker rod (or both) to operate the downhole pump.
- a single sucker rod may extend substantially an entire distance from the surface actuator to the downhole pump (typically thousands of meters), in which case the sucker rod is of the type known to those skilled in the art as a “continuous” sucker rod.
- many sucker rods e.g., having lengths of ⁇ 20-30 ft. or 6-9 m may be connected together, in order to extend the distance between the surface actuator and the downhole pump.
- FIG. 1 is a representative partially cross-sectional view of an example of a well system and associated method which can embody principles of this disclosure.
- FIG. 2 is a representative schematic view of an example of a sucker rod surface treatment method which can embody the principles of this disclosure.
- FIG. 3 is a representative schematic view of another example of the sucker rod surface treatment method.
- FIG. 4 is a representative perspective view of a sucker rod treated using the FIG. 3 method.
- FIG. 5 is a representative schematic view of another example of the sucker rod surface treatment method.
- FIG. 6 is a representative perspective view of a sucker rod treated using the FIG. 5 method.
- FIG. 7 is a representative schematic view of another example of the sucker rod surface treatment method.
- FIG. 8 is a representative perspective view of a sucker rod treated using the FIG. 7 method.
- FIG. 1 Representatively illustrated in FIG. 1 is a system 10 and associated method for use with a subterranean well, which system and method can embody principles of this disclosure.
- system 10 and method are merely one example of an application of the principles of this disclosure in practice, and a wide variety of other examples are possible. Therefore, the scope of this disclosure is not limited at all to the details of the system 10 and method described herein and/or depicted in the drawings.
- a walking beam-type surface pumping unit 12 is mounted on a pad 14 adjacent a wellhead 16 .
- a rod string 18 extends into the well and is connected to a downhole pump 20 in a tubing string 22 . Reciprocation of the rod string 18 by the pumping unit 12 causes the downhole pump 20 to pump fluids (such as, liquid hydrocarbons, gas, water, etc., and combinations thereof) from the well through the tubing string 22 to surface.
- fluids such as, liquid hydrocarbons, gas, water, etc., and combinations thereof
- the pumping unit 12 as depicted in FIG. 1 is of the type known to those skilled in the art as a “conventional” pumping unit.
- walking beam pumping units such as, those known to persons skilled in the art as Mark II, reverse Mark, beam-balanced and end-of-beam pumping units
- hydraulic, rotary or other types of pumping units may be used.
- the pumping unit 12 or other actuator may rotate the rod string 18 instead of, or in addition to, reciprocating the rod string.
- the scope of this disclosure is not limited to use of any particular type or configuration of pumping unit.
- the rod string 18 may comprise a substantially continuous rod, or may be made up of multiple connected together rods (also known as “sucker rods”).
- a polished rod 24 extends through a stuffing box 26 on the wellhead 16 .
- An outer surface of the polished rod 24 is finely polished to avoid damage to seals in the stuffing box 26 as the polished rod reciprocates upward and downward through the seals.
- a carrier bar 28 connects the polished rod 24 to a bridle 30 .
- the bridle 30 in this example comprises multiple cables that are secured to and wrap partially about a horsehead end of a beam of the pumping unit 12 .
- a hydraulic actuator, a motor or another type of actuator may be used to displace the polished rod 24 and the remainder of the rod string 18 .
- the rod string 18 includes the polished rod 24 , the sucker rod(s) 32 and any adapters/connectors used to operatively connect the rod string to the downhole pump 20 .
- the sucker rod 32 is exposed to fluids in the tubing, which may include corrosive agents (such as, acid gases in the production stream, CO 2 and/or H 2 S). This can lead to eventual failure, or the need to more frequently replace the sucker rod 32 .
- the sucker rod 32 is subject to damage due to shipping and handling, installation in the well and the pumping operation. If a corrosion resistant coating has been applied to the sucker rod 32 , the coating could be breached by impacts, wear and abrasion at any point during shipping, handling, installation and operation. It would be beneficial to be able to protect a corrosion resistant layer on a sucker rod from such damage.
- FIG. 2 an example of a sucker rod surface treatment method 34 is representatively illustrated in schematic form.
- the sucker rod 32 depicted in FIG. 2 may be used in the system 10 and method of FIG. 1 , or it may be used in other systems and methods.
- the sucker rod 32 traverses multiple stations 36 , 38 , 40 , 42 , 44 , 46 of a surface treatment system 48 as part of, or subsequent to, manufacture of the sucker rod.
- the surface treatment system 48 may include other stations, other numbers of stations and different combinations of stations.
- the scope of this disclosure is not limited to the particular stations, number of stations or combinations of stations in the surface treatment system 48 as described herein or depicted in the drawings.
- the method 34 may be performed prior to, or after, a base metal of the sucker rod 32 is in its final form.
- the method 34 may be performed for sucker rod 32 that is otherwise ready for installation in a well, or as part of initial manufacture of the sucker rod.
- the input drive 36 is used to displace the sucker rod 32 through the other stations 40 , 42 , 44 , 46 .
- An output drive 38 may be used instead of, or in addition to, the input drive 36 . If the surface treatment method 34 is part of an overall manufacturing operation, separate drives 36 , 38 may not be included in the surface treatment system 48 .
- the sucker rod 32 displaces from left to right through the stations 40 , 42 , 44 , 46 as viewed in FIG. 2 .
- the sucker rod 32 displaces first through the surface preparation station 40 (after the input drive 36 , if included), then through the heating station 42 and application stations 44 , 46 .
- the surface preparation station 40 in the FIG. 2 example includes an abrader 50 , a cleaner 52 and a dryer 54 .
- abrader 50 a cleaner 52 and a dryer 54 .
- other or different elements may be used in the surface preparation station 40 , or the surface preparation station may not be used or may be integrated with one or more other stations.
- the abrader 50 removes surface debris and any rust, and provides surface roughness for enhanced adherence of coatings, extrusions, layers, bonds, etc. later applied in the method 34 .
- the cleaner 52 removes undesired chemicals or other substances from the sucker rod surface.
- the cleaner 52 may use solvents, detergents or other cleaning agents for this purpose.
- the dryer 54 removes any remaining cleaner and any undesired particulate matter or other debris from the surface of the sucker rod 32 .
- the dryer 54 may produce a forced air flow, whether or not the air is also heated.
- the heating station 42 in the FIG. 2 example includes an induction heater 56 .
- the heater 56 may be integrated with one or more other stations (such as, one or both of the application stations 44 , 46 ).
- the application station 44 applies a corrosion resistant layer to the sucker rod 32 .
- the corrosion resistant layer is applied directly to the base metal of the sucker rod 32 , but in other examples a primer, an adhesive, a sealer or another type of layer may be applied to the base metal prior to the corrosion resistant layer being applied.
- the corrosion resistant layer may be applied using a spray or powder coating technique.
- the corrosion resistant layer may comprise a thermosetting polymer material (such as a fusion bond epoxy), in which case the heat provided by the heating station 42 is selected to cause the material to form a coating that completely encloses the base metal of the sucker rod 32 .
- the sucker rod 32 could be dipped or wrapped in a corrosion resistant material as the sucker rod passes through the application station 44 .
- the corrosion resistant layer could be extruded onto the base metal of the sucker rod 32 .
- the scope of this disclosure is not limited to any particular technique for incorporating the corrosion resistant layer into the sucker rod 32 .
- the application station 46 applies an abrasion resistant layer to the sucker rod 32 .
- the abrasion resistant layer is applied directly to the corrosion resistant layer of the sucker rod 32 , but in other examples a primer, an adhesive, a sealer or another type of layer may be applied to the corrosion resistant layer prior to the abrasion resistant layer being applied.
- the abrasion resistant layer may be applied using a spray or powder coating technique.
- the abrasion resistant layer may comprise a thermosetting polymer material (such as, a phenolic or a phenolic and fusion bond epoxy composition), in which case the heat provided by the heating station 42 is selected to cause the material to form a coating that completely encloses the corrosion resistant layer of the sucker rod 32 .
- the sucker rod 32 could be dipped or wrapped in an abrasion resistant material as the sucker rod passes through the application station 46 .
- the abrasion resistant layer could be extruded onto the corrosion resistant layer.
- the scope of this disclosure is not limited to any particular technique for incorporating the abrasion resistant layer into the sucker rod 32 .
- the abrasion resistant layer protects the corrosion resistant layer against damage due to impacts, wear and abrasion.
- the abrasion resistant layer can in some examples reduce friction between the sucker rod 32 and the tubing string 22 during operation.
- FIGS. 3 & 4 another example of the surface treatment system 48 and method 34 is representatively illustrated, along with an example sucker rod 32 produced by the system and method.
- the stations 40 , 42 , 44 , 46 are depicted in simplified form.
- the input and output drive stations 36 , 38 are not depicted in FIG. 3 , but could be included if desired.
- the sucker rod 32 is depicted with both of the corrosion resistant layer 58 and the abrasion resistant layer 60 on a base metal 62 .
- the corrosion resistant layer 58 is applied over the base metal 62 in the application station 44
- the abrasion resistant layer 60 is applied over the corrosion resistant layer 58 in the application station 46 .
- the base metal 62 may be any material suitable for transmitting work from the surface actuator 12 to the downhole pump 20 (see FIG. 1 ) and otherwise operating in a well environment. If the sucker rod 32 is a continuous sucker rod, the base metal 62 may have a length of 1000 meters or greater.
- the base metal 62 should have suitable strength and toughness for transmitting torque and tensile loads, particularly fatigue strength to withstand varying loads for long periods of time, and yet be economical to obtain and process.
- suitable materials for the base metal 62 include carbon and low alloy steels. However, the scope of this disclosure is not limited to use of any particular material in the base metal 62 .
- the corrosion resistant layer 58 is suitable for preventing corrosion of the base metal 62 due to exposure to fluids in a well.
- the corrosion resistant layer 58 comprises a corrosion resistant material 64 .
- suitable corrosion resistant materials include fusion bonded epoxy and other thermosetting polymers such as silicone, polyurethane, phenolic and polyester.
- the corrosion resistant material 64 may mitigate corrosion by isolating the base metal 62 from well fluids, by chemically hindering a corrosive reaction, or by another means.
- the corrosion resistant material 64 may be applied by spraying, dipping, wrapping, extruding or any other technique. The scope of this disclosure is not limited to use of any particular type of corrosion resistant material or manner of applying the corrosion resistant material.
- the corrosion resistant layer 58 is applied directly to the base metal 62 .
- an adhesive, primer, sealer or other layer may be included between the corrosion resistant layer 58 and the base metal 62 .
- the abrasion resistant layer 60 is suitable for preventing damage to the corrosion resistant layer 58 due to various impacts, wear and abrasion experienced by the sucker rod 32 .
- the abrasion resistant layer 60 comprises an abrasion resistant material 66 .
- suitable abrasion resistant materials include phenolics, fusion bonded epoxy and other thermosetting polymers, polyolefins and other thermoplastic polymers, hard particles or friction reducing particles, and combinations thereof.
- the abrasion resistant material 66 may mitigate abrasion by reducing friction, by presenting a hard or tough surface, or by another means.
- the abrasion resistant material 66 may be applied by spraying, dipping, wrapping, extruding or any other technique. The scope of this disclosure is not limited to use of any particular type of abrasion resistant material or manner of applying the abrasion resistant material.
- the abrasion resistant layer 60 is applied directly to the corrosion resistant layer 58 .
- an adhesive, primer, sealer or other layer may be included between the abrasion resistant layer 60 and the corrosion resistant layer 58 .
- FIGS. 5 & 6 another example of the surface treatment method 34 and system 48 , and the sucker rod 32 produced thereby, are representatively illustrated.
- the FIGS. 5 & 6 example is similar in many respects to the FIGS. 3 & 4 example, except that a particulate material 68 is applied over the corrosion resistant layer 58 .
- the particulate material 68 is applied by an application station 70 .
- the application station 70 is positioned between the application stations 44 , 46 as depicted in FIG. 5 .
- the particulate material 68 may be any material suitable to resist impact, wear or abrasion.
- the resistance to impact, wear or abrasion may be due to a relatively high strength, hardness or toughness of the particulate material 68 .
- the particulate material 68 may comprise silicon carbide, silicon dioxide (e.g., sand), carbides, nitrides, oxides, borides, minerals, or other suitable materials.
- the particulate material 68 may be selected from a variety of friction reducing agents, including fluorocarbons, graphite, graphene, molybdenum disulfide and other friction reducing agents. The scope of this disclosure is not limited to use of any certain particulate material.
- the application station 70 may apply the particulate material 68 directly to the corrosion resistant layer 58 , or another layer may be applied between the particulate material and the corrosion resistant layer.
- an adhesive could be applied to the corrosion resistant layer 58 prior to applying the particulate material 68 onto the adhesive.
- the particulate material 68 may embed partially or fully into the corrosion resistant layer 58 .
- the abrasion resistant layer 60 includes the particulate material 68 in a matrix material 66 a .
- the matrix material 66 a may be the same as the abrasion resistant material 66 in the FIGS. 3 & 4 example.
- the abrasion resistant material 66 in the FIGS. 5 & 6 example includes both the particulate material 68 and the matrix material 66 a.
- the particulate material 68 When the matrix material 66 a is applied to the corrosion resistant layer 58 , the particulate material 68 is “absorbed” into the matrix material, so that the matrix and particulate materials become a single composite element. In some examples, the particulate material 68 may become dispersed or embedded in the matrix material 66 a.
- FIGS. 7 & 8 another example of the surface treatment method 34 and system 48 , and the sucker rod 32 produced thereby, are representatively illustrated.
- the FIGS. 7 & 8 example is similar in many respects to the FIGS. 5 & 6 example, except that the abrasion resistant layer 60 (including the particulate material 68 and the matrix material 66 a ) is applied by the application station 46 .
- the abrasion resistant material 66 in this example includes both the matrix material 66 a and the particulate material 68 .
- the matrix and particulate materials 66 a , 68 may be combined to form the abrasion resistant material 66 , prior to the application station 46 applying the abrasion resistant material onto the corrosion resistant material 64 (or any layer applied on the corrosion resistant layer).
- the matrix material 66 a could comprise a thermoplastic material.
- the application station 46 can be configured to extrude the thermoplastic matrix material 66 a , along with the particulate material 68 embedded therein, onto the corrosion resistant layer 58 .
- the corrosion resistant material 64 comprises a thermosetting material
- an adhesive or other tie layer may be used between the corrosion resistant layer 58 and the abrasion resistant layer 60 .
- a corrosion resistant layer 58 is applied on a base metal 62 of a sucker rod 32 , and the corrosion resistant layer 58 is protected by an abrasion resistant layer 60 .
- An abrasion resistant material 66 of the abrasion resistant layer 60 may comprise a phenolic based matrix material 66 a and/or a particulate material 68 .
- the sucker rod 32 may comprise a base metal 62 configured to connect a surface actuator 12 to a downhole pump 20 , a corrosion resistant layer 58 on the base metal 62 , and an abrasion resistant layer 60 external to the corrosion resistant layer 58 .
- the abrasion resistant layer 60 comprises a phenolic material 66 a.
- the abrasion resistant layer 60 may further comprise an epoxy material.
- the abrasion resistant layer 60 may comprise an abrasion resistant particulate material 68 .
- the abrasion resistant layer 60 may comprise a friction reducing particulate material 68 .
- the particulate material 68 may be embedded in the phenolic material 66 a.
- the particulate material 68 may be positioned between the corrosion resistant layer 58 and at least a portion of the phenolic material 66 a.
- the particulate material 68 may be selected from the group consisting of silicon carbide, silicon dioxide, oxides, borides, nitrides and carbides.
- the particulate material 68 may be selected from a variety of friction reducing agents, including fluorocarbons, graphite, graphene, molybdenum disulfide and other friction reducing agents.
- the corrosion resistant layer 58 may comprise an epoxy material.
- the sucker rod 32 may be a continuous sucker rod.
- the base metal 62 may have a length of at least 1000 meters.
- the sucker rod 32 for use in a subterranean well is provided to the art by the above disclosure.
- the sucker rod 32 comprises a base metal 62 configured to connect a surface actuator 12 to a downhole pump 20 , a corrosion resistant layer 58 on the base metal 62 , and an abrasion resistant layer 60 external to the corrosion resistant layer 58 .
- the abrasion resistant layer 60 comprises an abrasion resistant particulate material 68 and a matrix material 66 a.
- the matrix material 66 a may comprise a phenolic material.
- the particulate material 68 may be embedded in the matrix material 66 a.
- the particulate material 68 may be positioned between the corrosion resistant layer 58 and at least a portion of the matrix material 66 a.
- a method 34 of producing a continuous sucker rod 32 is also provided to the art by the above method.
- the method 34 comprises displacing the continuous sucker rod 32 through a surface treatment system 48 ; applying a corrosion resistant layer 58 on a base metal 62 of the continuous sucker rod 32 ; then applying an abrasion resistant layer 60 external to the corrosion resistant layer 58 .
- the abrasion resistant layer 60 applying step may comprise applying a phenolic material 66 a.
- the abrasion resistant layer 60 applying step may comprise applying an abrasion resistant and/or friction reducing particulate material 68 .
- the abrasion resistant layer 60 applying step may comprise applying an abrasion resistant and/or friction reducing particulate material 68 dispersed in a matrix material 66 a.
Abstract
Description
- This disclosure relates generally to equipment utilized and operations performed in conjunction with a subterranean well and, in an example described below, more particularly provides a corrosion and abrasion resistant sucker rod.
- A sucker rod is typically used to transmit work from an actuator at surface to a downhole pump in a well. The actuator may reciprocate or rotate the sucker rod (or both) to operate the downhole pump.
- A single sucker rod may extend substantially an entire distance from the surface actuator to the downhole pump (typically thousands of meters), in which case the sucker rod is of the type known to those skilled in the art as a “continuous” sucker rod. In other situations, many sucker rods (e.g., having lengths of ˜20-30 ft. or 6-9 m) may be connected together, in order to extend the distance between the surface actuator and the downhole pump.
- Therefore, it will be appreciated that improvements are continually needed in the arts of designing, producing and utilizing sucker rods. The disclosure below provides such improvements.
-
FIG. 1 is a representative partially cross-sectional view of an example of a well system and associated method which can embody principles of this disclosure. -
FIG. 2 is a representative schematic view of an example of a sucker rod surface treatment method which can embody the principles of this disclosure. -
FIG. 3 is a representative schematic view of another example of the sucker rod surface treatment method. -
FIG. 4 is a representative perspective view of a sucker rod treated using theFIG. 3 method. -
FIG. 5 is a representative schematic view of another example of the sucker rod surface treatment method. -
FIG. 6 is a representative perspective view of a sucker rod treated using theFIG. 5 method. -
FIG. 7 is a representative schematic view of another example of the sucker rod surface treatment method. -
FIG. 8 is a representative perspective view of a sucker rod treated using theFIG. 7 method. - Representatively illustrated in
FIG. 1 is asystem 10 and associated method for use with a subterranean well, which system and method can embody principles of this disclosure. However, it should be clearly understood that thesystem 10 and method are merely one example of an application of the principles of this disclosure in practice, and a wide variety of other examples are possible. Therefore, the scope of this disclosure is not limited at all to the details of thesystem 10 and method described herein and/or depicted in the drawings. - In the
FIG. 1 example, a walking beam-typesurface pumping unit 12 is mounted on apad 14 adjacent awellhead 16. Arod string 18 extends into the well and is connected to adownhole pump 20 in atubing string 22. Reciprocation of therod string 18 by thepumping unit 12 causes thedownhole pump 20 to pump fluids (such as, liquid hydrocarbons, gas, water, etc., and combinations thereof) from the well through thetubing string 22 to surface. - The
pumping unit 12 as depicted inFIG. 1 is of the type known to those skilled in the art as a “conventional” pumping unit. However, in other examples, other types of walking beam pumping units (such as, those known to persons skilled in the art as Mark II, reverse Mark, beam-balanced and end-of-beam pumping units), hydraulic, rotary or other types of pumping units may be used. Thepumping unit 12 or other actuator may rotate therod string 18 instead of, or in addition to, reciprocating the rod string. Thus, the scope of this disclosure is not limited to use of any particular type or configuration of pumping unit. - The
rod string 18 may comprise a substantially continuous rod, or may be made up of multiple connected together rods (also known as “sucker rods”). At an upper end of therod string 18, apolished rod 24 extends through astuffing box 26 on thewellhead 16. An outer surface of the polishedrod 24 is finely polished to avoid damage to seals in thestuffing box 26 as the polished rod reciprocates upward and downward through the seals. - In the
FIG. 1 example, acarrier bar 28 connects the polishedrod 24 to abridle 30. Thebridle 30 in this example comprises multiple cables that are secured to and wrap partially about a horsehead end of a beam of thepumping unit 12. In other examples, a hydraulic actuator, a motor or another type of actuator may be used to displace the polishedrod 24 and the remainder of therod string 18. - As depicted in
FIG. 1 , therod string 18 includes thepolished rod 24, the sucker rod(s) 32 and any adapters/connectors used to operatively connect the rod string to thedownhole pump 20. It will be appreciated that thesucker rod 32 is exposed to fluids in the tubing, which may include corrosive agents (such as, acid gases in the production stream, CO2 and/or H2S). This can lead to eventual failure, or the need to more frequently replace thesucker rod 32. - In addition, the
sucker rod 32 is subject to damage due to shipping and handling, installation in the well and the pumping operation. If a corrosion resistant coating has been applied to thesucker rod 32, the coating could be breached by impacts, wear and abrasion at any point during shipping, handling, installation and operation. It would be beneficial to be able to protect a corrosion resistant layer on a sucker rod from such damage. - Referring additionally now to
FIG. 2 , an example of a sucker rodsurface treatment method 34 is representatively illustrated in schematic form. Thesucker rod 32 depicted inFIG. 2 may be used in thesystem 10 and method ofFIG. 1 , or it may be used in other systems and methods. - In the
FIG. 2 method 34, thesucker rod 32 traversesmultiple stations surface treatment system 48 as part of, or subsequent to, manufacture of the sucker rod. In other examples, thesurface treatment system 48 may include other stations, other numbers of stations and different combinations of stations. Thus, the scope of this disclosure is not limited to the particular stations, number of stations or combinations of stations in thesurface treatment system 48 as described herein or depicted in the drawings. - The
method 34 may be performed prior to, or after, a base metal of thesucker rod 32 is in its final form. Themethod 34 may be performed forsucker rod 32 that is otherwise ready for installation in a well, or as part of initial manufacture of the sucker rod. - The
input drive 36 is used to displace thesucker rod 32 through theother stations output drive 38 may be used instead of, or in addition to, theinput drive 36. If thesurface treatment method 34 is part of an overall manufacturing operation,separate drives surface treatment system 48. - The
sucker rod 32 displaces from left to right through thestations FIG. 2 . Thus, thesucker rod 32 displaces first through the surface preparation station 40 (after theinput drive 36, if included), then through theheating station 42 andapplication stations - The
surface preparation station 40 in theFIG. 2 example includes anabrader 50, acleaner 52 and adryer 54. In other examples, other or different elements may be used in thesurface preparation station 40, or the surface preparation station may not be used or may be integrated with one or more other stations. - The
abrader 50 removes surface debris and any rust, and provides surface roughness for enhanced adherence of coatings, extrusions, layers, bonds, etc. later applied in themethod 34. - The
cleaner 52 removes undesired chemicals or other substances from the sucker rod surface. Thecleaner 52 may use solvents, detergents or other cleaning agents for this purpose. - The
dryer 54 removes any remaining cleaner and any undesired particulate matter or other debris from the surface of thesucker rod 32. Thedryer 54 may produce a forced air flow, whether or not the air is also heated. - The
heating station 42 in theFIG. 2 example includes aninduction heater 56. In other examples, other types of heaters may be used, or theheater 56 may be integrated with one or more other stations (such as, one or both of theapplication stations 44, 46). - The
application station 44 applies a corrosion resistant layer to thesucker rod 32. In this example, the corrosion resistant layer is applied directly to the base metal of thesucker rod 32, but in other examples a primer, an adhesive, a sealer or another type of layer may be applied to the base metal prior to the corrosion resistant layer being applied. - The corrosion resistant layer may be applied using a spray or powder coating technique. The corrosion resistant layer may comprise a thermosetting polymer material (such as a fusion bond epoxy), in which case the heat provided by the
heating station 42 is selected to cause the material to form a coating that completely encloses the base metal of thesucker rod 32. - In other examples, the
sucker rod 32 could be dipped or wrapped in a corrosion resistant material as the sucker rod passes through theapplication station 44. The corrosion resistant layer could be extruded onto the base metal of thesucker rod 32. Thus, the scope of this disclosure is not limited to any particular technique for incorporating the corrosion resistant layer into thesucker rod 32. - The
application station 46 applies an abrasion resistant layer to thesucker rod 32. In this example, the abrasion resistant layer is applied directly to the corrosion resistant layer of thesucker rod 32, but in other examples a primer, an adhesive, a sealer or another type of layer may be applied to the corrosion resistant layer prior to the abrasion resistant layer being applied. - The abrasion resistant layer may be applied using a spray or powder coating technique. The abrasion resistant layer may comprise a thermosetting polymer material (such as, a phenolic or a phenolic and fusion bond epoxy composition), in which case the heat provided by the
heating station 42 is selected to cause the material to form a coating that completely encloses the corrosion resistant layer of thesucker rod 32. - In other examples, the
sucker rod 32 could be dipped or wrapped in an abrasion resistant material as the sucker rod passes through theapplication station 46. The abrasion resistant layer could be extruded onto the corrosion resistant layer. Thus, the scope of this disclosure is not limited to any particular technique for incorporating the abrasion resistant layer into thesucker rod 32. - The abrasion resistant layer protects the corrosion resistant layer against damage due to impacts, wear and abrasion. In addition, the abrasion resistant layer can in some examples reduce friction between the
sucker rod 32 and thetubing string 22 during operation. - Referring additionally now to
FIGS. 3 & 4 , another example of thesurface treatment system 48 andmethod 34 is representatively illustrated, along with anexample sucker rod 32 produced by the system and method. InFIG. 3 , thestations output drive stations FIG. 3 , but could be included if desired. - In
FIG. 4 , thesucker rod 32 is depicted with both of the corrosionresistant layer 58 and the abrasionresistant layer 60 on abase metal 62. The corrosionresistant layer 58 is applied over thebase metal 62 in theapplication station 44, and the abrasionresistant layer 60 is applied over the corrosionresistant layer 58 in theapplication station 46. - The
base metal 62 may be any material suitable for transmitting work from thesurface actuator 12 to the downhole pump 20 (seeFIG. 1 ) and otherwise operating in a well environment. If thesucker rod 32 is a continuous sucker rod, thebase metal 62 may have a length of 1000 meters or greater. - The
base metal 62 should have suitable strength and toughness for transmitting torque and tensile loads, particularly fatigue strength to withstand varying loads for long periods of time, and yet be economical to obtain and process. Some examples of suitable materials for thebase metal 62 include carbon and low alloy steels. However, the scope of this disclosure is not limited to use of any particular material in thebase metal 62. - In this example, the corrosion
resistant layer 58 is suitable for preventing corrosion of thebase metal 62 due to exposure to fluids in a well. The corrosionresistant layer 58 comprises a corrosionresistant material 64. Examples of suitable corrosion resistant materials include fusion bonded epoxy and other thermosetting polymers such as silicone, polyurethane, phenolic and polyester. - The corrosion
resistant material 64 may mitigate corrosion by isolating thebase metal 62 from well fluids, by chemically hindering a corrosive reaction, or by another means. The corrosionresistant material 64 may be applied by spraying, dipping, wrapping, extruding or any other technique. The scope of this disclosure is not limited to use of any particular type of corrosion resistant material or manner of applying the corrosion resistant material. - In the
FIGS. 3 & 4 example, the corrosionresistant layer 58 is applied directly to thebase metal 62. In some examples, an adhesive, primer, sealer or other layer may be included between the corrosionresistant layer 58 and thebase metal 62. - The abrasion
resistant layer 60 is suitable for preventing damage to the corrosionresistant layer 58 due to various impacts, wear and abrasion experienced by thesucker rod 32. The abrasionresistant layer 60 comprises an abrasionresistant material 66. Examples of suitable abrasion resistant materials include phenolics, fusion bonded epoxy and other thermosetting polymers, polyolefins and other thermoplastic polymers, hard particles or friction reducing particles, and combinations thereof. - The abrasion
resistant material 66 may mitigate abrasion by reducing friction, by presenting a hard or tough surface, or by another means. The abrasionresistant material 66 may be applied by spraying, dipping, wrapping, extruding or any other technique. The scope of this disclosure is not limited to use of any particular type of abrasion resistant material or manner of applying the abrasion resistant material. - In the
FIGS. 3 & 4 example, the abrasionresistant layer 60 is applied directly to the corrosionresistant layer 58. In some examples, an adhesive, primer, sealer or other layer may be included between the abrasionresistant layer 60 and the corrosionresistant layer 58. - Referring additionally now to
FIGS. 5 & 6 , another example of thesurface treatment method 34 andsystem 48, and thesucker rod 32 produced thereby, are representatively illustrated. TheFIGS. 5 & 6 example is similar in many respects to theFIGS. 3 & 4 example, except that aparticulate material 68 is applied over the corrosionresistant layer 58. - The
particulate material 68 is applied by anapplication station 70. Theapplication station 70 is positioned between theapplication stations FIG. 5 . - The
particulate material 68 may be any material suitable to resist impact, wear or abrasion. The resistance to impact, wear or abrasion may be due to a relatively high strength, hardness or toughness of theparticulate material 68. Theparticulate material 68 may comprise silicon carbide, silicon dioxide (e.g., sand), carbides, nitrides, oxides, borides, minerals, or other suitable materials. Theparticulate material 68 may be selected from a variety of friction reducing agents, including fluorocarbons, graphite, graphene, molybdenum disulfide and other friction reducing agents. The scope of this disclosure is not limited to use of any certain particulate material. - The
application station 70 may apply theparticulate material 68 directly to the corrosionresistant layer 58, or another layer may be applied between the particulate material and the corrosion resistant layer. For example, an adhesive could be applied to the corrosionresistant layer 58 prior to applying theparticulate material 68 onto the adhesive. Theparticulate material 68 may embed partially or fully into the corrosionresistant layer 58. - The remainder of the abrasion
resistant layer 60 is applied by theapplication station 46, for example, as described above for theFIGS. 3 & 4 example. However, in theFIGS. 5 & 6 example, the abrasionresistant layer 60 includes theparticulate material 68 in amatrix material 66 a. Thematrix material 66 a may be the same as the abrasionresistant material 66 in theFIGS. 3 & 4 example. Thus, the abrasionresistant material 66 in theFIGS. 5 & 6 example includes both theparticulate material 68 and thematrix material 66 a. - When the
matrix material 66 a is applied to the corrosionresistant layer 58, theparticulate material 68 is “absorbed” into the matrix material, so that the matrix and particulate materials become a single composite element. In some examples, theparticulate material 68 may become dispersed or embedded in thematrix material 66 a. - Referring additionally now to
FIGS. 7 & 8 , another example of thesurface treatment method 34 andsystem 48, and thesucker rod 32 produced thereby, are representatively illustrated. TheFIGS. 7 & 8 example is similar in many respects to theFIGS. 5 & 6 example, except that the abrasion resistant layer 60 (including theparticulate material 68 and thematrix material 66 a) is applied by theapplication station 46. - The abrasion
resistant material 66 in this example includes both thematrix material 66 a and theparticulate material 68. The matrix andparticulate materials resistant material 66, prior to theapplication station 46 applying the abrasion resistant material onto the corrosion resistant material 64 (or any layer applied on the corrosion resistant layer). - In some examples, the
matrix material 66 a could comprise a thermoplastic material. Theapplication station 46 can be configured to extrude thethermoplastic matrix material 66 a, along with theparticulate material 68 embedded therein, onto the corrosionresistant layer 58. However, if the corrosionresistant material 64 comprises a thermosetting material, an adhesive or other tie layer may be used between the corrosionresistant layer 58 and the abrasionresistant layer 60. - It may now be fully appreciated that the above disclosure provides significant advancements to the art of designing, producing and utilizing sucker rods for use in wells. In examples described above, a corrosion
resistant layer 58 is applied on abase metal 62 of asucker rod 32, and the corrosionresistant layer 58 is protected by an abrasionresistant layer 60. An abrasionresistant material 66 of the abrasionresistant layer 60 may comprise a phenolic basedmatrix material 66 a and/or aparticulate material 68. - The above disclosure provides to the art a
sucker rod 32 for use in a subterranean well. In one example, thesucker rod 32 may comprise abase metal 62 configured to connect asurface actuator 12 to adownhole pump 20, a corrosionresistant layer 58 on thebase metal 62, and an abrasionresistant layer 60 external to the corrosionresistant layer 58. The abrasionresistant layer 60 comprises aphenolic material 66 a. - In any of the examples described herein, the abrasion
resistant layer 60 may further comprise an epoxy material. - In any of the examples described herein, the abrasion
resistant layer 60 may comprise an abrasion resistantparticulate material 68. - In any of the examples described herein, the abrasion
resistant layer 60 may comprise a friction reducingparticulate material 68. - In any of the examples described herein, the
particulate material 68 may be embedded in thephenolic material 66 a. - In any of the examples described herein, the
particulate material 68 may be positioned between the corrosionresistant layer 58 and at least a portion of thephenolic material 66 a. - In any of the examples described herein, the
particulate material 68 may be selected from the group consisting of silicon carbide, silicon dioxide, oxides, borides, nitrides and carbides. - In any of the examples described herein, the
particulate material 68 may be selected from a variety of friction reducing agents, including fluorocarbons, graphite, graphene, molybdenum disulfide and other friction reducing agents. - In any of the examples described herein, the corrosion
resistant layer 58 may comprise an epoxy material. - In any of the examples described herein, the
sucker rod 32 may be a continuous sucker rod. - In any of the examples described herein, the
base metal 62 may have a length of at least 1000 meters. - Another
sucker rod 32 for use in a subterranean well is provided to the art by the above disclosure. In this example, thesucker rod 32 comprises abase metal 62 configured to connect asurface actuator 12 to adownhole pump 20, a corrosionresistant layer 58 on thebase metal 62, and an abrasionresistant layer 60 external to the corrosionresistant layer 58. The abrasionresistant layer 60 comprises an abrasion resistantparticulate material 68 and amatrix material 66 a. - In any of the examples described herein, the
matrix material 66 a may comprise a phenolic material. - In any of the examples described herein, the
particulate material 68 may be embedded in thematrix material 66 a. - In any of the examples described herein, the
particulate material 68 may be positioned between the corrosionresistant layer 58 and at least a portion of thematrix material 66 a. - A
method 34 of producing acontinuous sucker rod 32 is also provided to the art by the above method. In one example, themethod 34 comprises displacing thecontinuous sucker rod 32 through asurface treatment system 48; applying a corrosionresistant layer 58 on abase metal 62 of thecontinuous sucker rod 32; then applying an abrasionresistant layer 60 external to the corrosionresistant layer 58. - In any of the examples described herein, the abrasion
resistant layer 60 applying step may comprise applying aphenolic material 66 a. - In any of the examples described herein, the abrasion
resistant layer 60 applying step may comprise applying an abrasion resistant and/or friction reducingparticulate material 68. - In any of the examples described herein, the abrasion
resistant layer 60 applying step may comprise applying an abrasion resistant and/or friction reducingparticulate material 68 dispersed in amatrix material 66 a. - Although various examples have been described above, with each example having certain features, it should be understood that it is not necessary for a particular feature of one example to be used exclusively with that example.
- Instead, any of the features described above and/or depicted in the drawings can be combined with any of the examples, in addition to or in substitution for any of the other features of those examples. One example's features are not mutually exclusive to another example's features. Instead, the scope of this disclosure encompasses any combination of any of the features.
- Although each example described above includes a certain combination of features, it should be understood that it is not necessary for all features of an example to be used. Instead, any of the features described above can be used, without any other particular feature or features also being used.
- It should be understood that the various embodiments described herein may be utilized in various orientations, such as inclined, inverted, horizontal, vertical, etc., and in various configurations, without departing from the principles of this disclosure. The embodiments are described merely as examples of useful applications of the principles of the disclosure, which is not limited to any specific details of these embodiments.
- The terms “including,” “includes,” “comprising,” “comprises,” and similar terms are used in a non-limiting sense in this specification. For example, if a system, method, apparatus, device, etc., is described as “including” a certain feature or element, the system, method, apparatus, device, etc., can include that feature or element, and can also include other features or elements. Similarly, the term “comprises” is considered to mean “comprises, but is not limited to.”
- Of course, a person skilled in the art would, upon a careful consideration of the above description of representative embodiments of the disclosure, readily appreciate that many modifications, additions, substitutions, deletions, and other changes may be made to the specific embodiments, and such changes are contemplated by the principles of this disclosure. For example, structures disclosed as being separately formed can, in other examples, be integrally formed and vice versa. Accordingly, the foregoing detailed description is to be clearly understood as being given by way of illustration and example only, the spirit and scope of the invention being limited solely by the appended claims and their equivalents.
Claims (23)
Priority Applications (6)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
US16/276,658 US20200263508A1 (en) | 2019-02-15 | 2019-02-15 | Corrosion and abrasion resistant sucker rod |
CA3126809A CA3126809A1 (en) | 2019-02-15 | 2020-01-17 | Corrosion and abrasion resistant sucker rod |
MX2021009809A MX2021009809A (en) | 2019-02-15 | 2020-01-17 | Corrosion and abrasion resistant sucker rod. |
PCT/US2020/014094 WO2020167413A1 (en) | 2019-02-15 | 2020-01-17 | Corrosion and abrasion resistant sucker rod |
EP20704988.3A EP3924594A1 (en) | 2019-02-15 | 2020-01-17 | Corrosion and abrasion resistant sucker rod |
CONC2021/0009579A CO2021009579A2 (en) | 2019-02-15 | 2021-07-22 | Corrosion and abrasion resistant suction rod |
Applications Claiming Priority (1)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
US16/276,658 US20200263508A1 (en) | 2019-02-15 | 2019-02-15 | Corrosion and abrasion resistant sucker rod |
Publications (1)
Publication Number | Publication Date |
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US20200263508A1 true US20200263508A1 (en) | 2020-08-20 |
Family
ID=69570841
Family Applications (1)
Application Number | Title | Priority Date | Filing Date |
---|---|---|---|
US16/276,658 Abandoned US20200263508A1 (en) | 2019-02-15 | 2019-02-15 | Corrosion and abrasion resistant sucker rod |
Country Status (6)
Country | Link |
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US (1) | US20200263508A1 (en) |
EP (1) | EP3924594A1 (en) |
CA (1) | CA3126809A1 (en) |
CO (1) | CO2021009579A2 (en) |
MX (1) | MX2021009809A (en) |
WO (1) | WO2020167413A1 (en) |
Cited By (1)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
WO2022061399A1 (en) * | 2020-09-22 | 2022-03-31 | Oilfield Piping Systems Pty Ltd | Sucker rod guide |
Family Cites Families (6)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US4045591A (en) * | 1974-07-19 | 1977-08-30 | Rodco, Inc. | Method of treating sucker rod |
AU2016247078B2 (en) * | 2010-02-17 | 2018-12-20 | Baker Hughes, A Ge Company, Llc | Nano-coatings for articles |
WO2011102820A1 (en) * | 2010-02-22 | 2011-08-25 | Exxonmobil Research And Engineering Company | Coated sleeved oil and gas well production devices |
US9869135B1 (en) * | 2012-06-21 | 2018-01-16 | Rfg Technology Partners Llc | Sucker rod apparatus and methods for manufacture and use |
US10871256B2 (en) * | 2015-07-27 | 2020-12-22 | Schlumberger Technology Corporation | Property enhancement of surfaces by electrolytic micro arc oxidation |
US20170283958A1 (en) * | 2016-04-01 | 2017-10-05 | Weatherford Technology Holdings, Llc | Dual layer fusion bond epoxy coating for continuous sucker rod |
-
2019
- 2019-02-15 US US16/276,658 patent/US20200263508A1/en not_active Abandoned
-
2020
- 2020-01-17 CA CA3126809A patent/CA3126809A1/en active Pending
- 2020-01-17 WO PCT/US2020/014094 patent/WO2020167413A1/en unknown
- 2020-01-17 MX MX2021009809A patent/MX2021009809A/en unknown
- 2020-01-17 EP EP20704988.3A patent/EP3924594A1/en not_active Withdrawn
-
2021
- 2021-07-22 CO CONC2021/0009579A patent/CO2021009579A2/en unknown
Cited By (1)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
WO2022061399A1 (en) * | 2020-09-22 | 2022-03-31 | Oilfield Piping Systems Pty Ltd | Sucker rod guide |
Also Published As
Publication number | Publication date |
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MX2021009809A (en) | 2021-09-08 |
CO2021009579A2 (en) | 2021-08-09 |
WO2020167413A1 (en) | 2020-08-20 |
CA3126809A1 (en) | 2020-08-20 |
EP3924594A1 (en) | 2021-12-22 |
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