US20080029305A1

US20080029305A1 - Mechanical parts having increased wear resistance

Info

Publication number: US20080029305A1
Application number: US11/788,798
Authority: US
Inventors: Habib Skaff
Original assignee: Skaff Corp of America
Current assignee: Skaff Corp of America
Priority date: 2006-04-20
Filing date: 2007-04-20
Publication date: 2008-02-07
Also published as: MX2008013386A; CA2649525A1; WO2007124018A2; WO2007124018A3

Abstract

Borided parts for wear surfaces in equipment for use in earth boring, well completion and fluid extraction are provided.

Description

CROSS-REFERENCE TO RELATED APPLICATIONS

This application claims priority to U.S. Provisional patent application Ser. No. 60/745,228, filed Apr. 20, 2006, the entirety of which is hereby incorporated herein by reference.

FIELD OF THE INVENTION

This invention pertains of borided parts for wear surfaces in equipment for use in earth boring, well completion and fluid extraction.

BACKGROUND OF THE INVENTION

Oil exploration is a specialized process that combines elegant scientific models and brute force prospecting. Seismic prospecting techniques employ sound waves to find probable oil reserves thousands of feet below the Earth's surface, and sophisticated modeling techniques are used to characterize the geology of those locations. Once a likely site is identified, a hole is drilled into the ground until oil or gas is found or the driller decides to abandon the site for a likelier prospect. At some sites, the hole is drilled using a top head drive attached to a length of hollow pipe. As the hole becomes deeper, extra sections are added to the pipe. In addition, a continuous stream of drilling “mud,” an aqueous slurry containing clay and other chemicals, is pumped through the drill pipe and through holes in the drill bit to cool the bit. The mud also coats the side of the hole to prevent collapse and carries crushed rock to the surface. The mud is pumped into the hole by a mud, or slush, pump.
The drill bit has to cut through rock and gradually wears. In addition, the mud and the cuttings traveling to the surface wear not only the drill bit but components of the mud pump. Drilling (and mud pumping) is conducted 24 hours a day, but if any of the parts wear out, the entire operation may need to be halted while the part is repaired. The components of the mud pump, located at the surface, are easily accessible. On the other hand, the entire length of thousands of feet of hollow pipe have to be removed section by section to replace the drill bit. As a result, it is desirable to increase the useable lifetime of all the wearing parts used in oil drilling.

DEFINITIONA

As used herein, the terms “boriding” and “boronizing” are used interchangeably and indicate the development of a boron-containing layer on a metal substrate, such that boron diffuses into the metal and reacts with a component of the metal or a component of the metal diffuses to the boron-containing layer and reacts with the boron, or both.
As used herein, the term “fluid extraction” refers to the removal of oil, natural gas, water, and/or other fluids from underground.
As used herein, the term “metallic” refers to a material that includes at least 50% metal elements (e.g., Fe, Ti, Zn, etc.) in a metallic, intermetallic, or alloy phase. In some embodiment, the material may include at least 60%, at least 70%, at least 80%, at least 90%, or at least 95% metal elements in a metallic, intermetallic, or alloy phase.
As used herein, the terms “mud pump” and “slush pump” are used interchangeably.

BRIEF DESCRIPTION OF THE DRAWINGS

The invention is described with reference to the several figures of the drawing, in which,
FIG. 1 is an exploded view of a piston and liner for use in an exemplary mud pump (Gardner Denver Service Manual 15-504).
FIG. 2 is a cross-sectional view of an exemplary mud pump (Gardner Denver Service Manual 15-603, page 11)
FIG. 3 is an exploded view of a valve for use in an exemplary mud pump (Gardner Denver Service Manual 15-504 p 9).
FIGS. 4A and B are micrographs of cross-sections of two steel samples after boriding at A) 1700° F. for 8 hr and B) 1500° F. for 24 hr.
FIG. 5 is a graph illustrating the change of hardness (HV₅₀) with depth for various borided components (1V and 2V: Valve bodies; 1S and 2S: Valve seats).

DETAILED DESCRIPTION OF CERTAIN EMBODIMENTS OF THE INVENTION

In one embodiment, at least a first portion of a surface of a component for use in combination with a second component during earth-boring, well completion (e.g., fracturing and cementing the well after drilling), or fluid extraction comprises a metallic material and is borided. In certain embodiments, the borided portion does not wear against a metallic surface of the second component during use. In some embodiments, the component is not a tricone bit. The component may be fabricated from a ferrous or non-ferrous metal or metal alloy. In some embodiments, the metal or metal alloy may be steel, titanium, or a titanium or chromium alloy. In certain embodiments, the first portion is substantially metallic, or may be at least 80% metallic, at least 85% metallic, at least 90% metallic, or at least 95% metallic.
Various equipment for use in earth-boring, well completion, and fluid extraction can benefit from the teachings of the invention. During exploration and drilling for fluids such as oil, natural gas, and water, drilling hardware is subjected to abrasive, erosive, and corrosive conditions. These wear modes reduce the useful life of hardware components and increase drill rig operating costs. The teeth of drill bits used in oil and gas exploration and drilling are often made from cemented tungsten carbide, due to its resistance to abrasion and erosion. However, due to the difficult nature of working with tungsten carbide, fabrication of the teeth for drill bits is complex, labor intensive, and costly. Steel teeth, which are easier and less costly to fabricate, are sometimes used, however they may not be sufficiently wear-resistant for some applications. The surface of the drill bit, the roller cones to which the teeth are secured, and the nozzle from which drilling mud is directed into the drill hole are often fabricated from steel as well. Boriding can increase the wear resistance of all of these components, allowing them to be fabricated from steel or other metals instead of tungsten carbide or other cermets or metal-matrix composites. Wear also is a problem for many other components used in oil and gas drilling, such as, for example, radial and thrust bearings, mechanical couplings, wear pads, flow diverters and restrictors, mud pump liners, and impellers.
Additional parts that may benefit from boriding include various fishing tools, apparatus to recover parts from within a bore. Because these components tap a thread in the component to secure themselves to the component, they often can only be used once for a particular size component, after which the tap/thread is too worn to recover a second component of the same size. These tools are often tapered and thus can be used to recover a component having a larger diameter even after the smaller diameter regions become worn. However, boriding can harden the surface sufficiently that the fishing tool can be used two or more times to recover parts from a bore. Exemplary fishing tools include but are not limited to spears, taper taps, and overshots.
Many other components of exploration and drilling equipment are subject to wear by corrosion, abrasion, or erosion, including, for example, radial and thrust bearings, mechanical couplings, wear pads, flow diverters and restrictors, mud and cement pump liners and impellers, drill pipes, valves, directional drilling assemblies, hanger assemblies, fishing tools (e.g., spears, taper taps, and overshots), percussion assemblies, nozzles, and core lifters. Many different coating methods have been tried for improving the abrasion and corrosion resistance of these components. These include thermal spraying and application carbide composite coatings, as well as nickel and chrome plating. While these coatings can improve the life of the part, further improvements can provide dramatic decreases in downtime and replacement costs.
During earth-boring, mud pumps are used to circulate pumping mud in the drill hole as the mud carries cuttings to the surface. The extent and mode of wear to the pump components is determined by the abrasiveness, particle concentration, particle size, velocity, pH, and other characteristics of the particles and the fluid as well as the operating conditions of the pump such as flow rate, pressure, etc. Depending on the site, pumps may need to run continuously for weeks or months at a time. Wear results in part from the flow of particles within the mud abrading the surfaces of the pump's components. As the surfaces of these components wear away even a small amount, the ability of a pump to maintain pressure and convey the pumping mud becomes greatly diminished. When pump components wear beyond a certain limit and begin to perform below acceptable process limits, the pumps and/or process lines must be shut down and the components or entire pumps must be replaced.
In an exemplary embodiment, at least some of the metal bearing surfaces of a mud, or slush, pump are borided. FIG. 1 is an exploded view of an exemplary piston for use in an exemplary mud pump. Piston rod 1, pump liner 5, and piston hub 6 all have metal bearing surfaces. FIG. 2 is a cross-sectional view of a mud pump. In addition to the piston and its associated components, the pump also includes two valves 20, shown in exploded view in FIG. 3. Both valve body 23 and valve seat 24 have metallic bearing surfaces. It is contemplated that all of these components can experience improved tribological properties and performance as a result of boriding.
It is contemplated that other components employed in earth-boring, well completion, and fluid extraction may also benefit from boriding. For example, DTH (down the hole) hammer bits wear against rock as they drill the well, while the internal components of the hammers wear against each other. While these hammer bits often have carbide inserts, it is contemplated that the lifetime of the metallic portions of the hammer bit may also be extended by boriding. Fracturing tubes may be abraded and/or corroded by the fracturing fluid. Valve seats and valve bodies abrade against the pumping mud but also against each other. Drill pipes are initially abraded by the pumping mud, foam (air drilling), brine, and the rock it carries out of the well and later by fluids being extracted by the well and any particulate matter they carry. Drill pipes may also be corroded by fluids such as water that are pumped into the well. Abrasion of core lifters can reduce the length of cores that can be cut and brought to the surface and, in extreme cases, can jeopardize the cohesion of the core sample, making recovery difficult. Directional drilling assemblies may experience uneven wear as a result of the deviation of the drilling direction from the vertical. Plungers for cement pumps abrade against the rocks in the cement and are also chemically eroded by the elevated pH of lime-based materials. Flow diverters and flow restrictors may wear not only from particulates in the extracted fluid but also from the fluid itself. It is contemplated that boriding of radial and thrust bearings may not only reduce wear but may also reduce fatigue by reducing friction during use. Additional parts that may benefit from boriding include but are not limited to mechanical couplings, wear pads, impellers, hanger assemblies, percussion assemblies, nozzles, rollers, cams, and shafts.
As discussed above, the lifetime of drilling and pump parts that are constantly abraded by rock from a well is determined in part by the tribological properties of the components. The use of diffusion-based treatments such as nitriding, carburization, and boriding to increase surface hardness and resistance to wear is well known. Boriding can produce a harder surface than nitriding or carburization and is suitable for some steel alloys for which nitriding or carburization are less optimal. Boriding also improves the corrosion resistance and reduces the coefficient of friction more than carburization, increasing the lifetime of parts. Even a 10% improvement in part life can create immense savings over the course of drilling and completing a single well. Other techniques for increasing surface hardness include the simple deposition of a boron-containing layer at the surface of a material. For example, electrochemistry may be employed to form a layer of iron boride at the surface of a component. Alternatively, superabrasive composites including materials such as diamond or cubic boron nitride may be electroplated onto metallic components, or metal/metal boride mixtures may be thermally sprayed onto components. However, layers formed by these methods may not be chemically or mechanically integrated with the bulk material. Boriding provides greater integration of the boron-containing layer with the substrate. This integration increases the strength of the interface between the boride-containing layer and the substrate, further reducing galling, tearing, seizing, and other forms of wear in which a material flakes from the surface.
A variety of boriding techniques may be used to improve the tribology of wearing parts for use in earth-boring, well completion, and fluid extraction. In some embodiments, boriding includes two processes: the generation of a thin boride layer at the surface of the material and the growth of that layer by diffusion into the bulk material. In some cases, the depth of the boron-containing diffusion zone may be over seven times thicker than the surface boride layer (ASM Handbook, Volume 4, ASM International, Materials Park, Ohio, 1994). The diffusion layer increases the resistance of the layer to delamination and also helps reduce cracking resulting from differential rates of thermal expansion during processing. In addition, diffusion of the boron into the bulk material may improve the fatigue performance of the component.
An exemplary boriding method is pack boriding. A boron-containing powder is packed around a workpiece in a refractory container and heated. Alternatively, a paste may be applied to the workpiece and heated, or a fluidized bed may be employed. In another embodiment, boriding may be performed with a gas or plasma, allowing the boriding to be performed without annealing the core of the work piece, which can lead to grain coarsening and softening of the base material. Plasma boriding also allows quicker diffusion of reactive elements and higher velocity impact of reactive boron species against the surface of the workpiece. In some embodiments, it may be desirable to have a hardened surface around a more malleable core. The surface heating imposed during plasma boriding allows the difference in mechanical properties between the various regions of the part to be maintained. Exemplary boriding methods are disclosed in U.S. Pat. Nos. 3,926,327, 4,610,437, 4,637,837, and 6,783,794. In another embodiment, a potassium haloborate may be decomposed to the potassium halide salt and the boron trihalide, which is then fed into an inert gas stream for plasma boriding. In one embodiment, the potassium haloborate is potassium fluoroborate. It is contemplated that this technique facilitates boriding of larger parts more cheaply and safely than plasma boriding techniques employing organoborates or boron halides.
It is contemplated that use of boriding to surface harden components allows them to be made from materials that are not traditionally employed in earth-boring. For example, pump liners are often fabricated from chromium-containing steels. However, the use of a borided surface may enable these components to be fabricated from chromium alloys, titanium, and titanium alloys, for example, Ti-6Al-4V, Ti-6Al-6V-2Sn, Ti-10V-2Fe-3Al, Ti-0.3Mo-0.8Ni, Ti-0.2Pd, etc. TiB₂has a hardness of 3300 vickers, which can greatly improve the lifetime of components fabricated from borided titanium-containing metals.
In another embodiment, a system for preparing a well for fluid extraction includes a first component having a surface, at least a first portion of which comprises a metallic material that is borided. In certain embodiments, the system further includes a second component having a metallic portion, and the first portion does not wear against the metallic portion during use. In certain embodiments, the component is not a tricone bit. In certain embodiments, the system includes a drill, a mud pump, a cement pump, and/or a fracturing tube. The system may also include segments of a well liner.
In a further embodiment, a method of preparing a component for wearing against a material transported during earth-boring, well completion, or fluid extraction, the component having a surface, at least a portion of which comprises a metallic material, includes boriding at least the first portion. In certain embodiments, the component is not a tricone bit.
In a further embodiment, at least a first portion of an interior surface of a pump liner for use in earth-boring, well completion, or fluid extraction is borided. In another embodiment, a first portion of a surface of a component for use in earth-boring, well completion, or fluid extraction includes a substantially metallic material that is borided. According to another embodiment of the invention, the component is a valve seat, valve body, mud pump liner, piston hub, sucker rod, piston rod, fishing tool, or plunger.

EXEMPLIFICATION

EXAMPLE 1

Boronization of Valve Seat and Valve Body

A valve seat and valve body were borided by pack boriding. One sample was borided for 8 hours at 1700° F.; the second was treated for 24 hours at 1500° F. Micrographs of the boride layer, showing the sawtooth pattern frequently observed in borided steels, are shown in FIGS. 4A and B. The sample treated at 1700° F. had a solid boride layer of 0.0041″ and a total boride layer depth of 0.0064″. The sample treated at 1500° F. had a solid boride layer of 0.0037″ and a total boride layer depth of 0.0046″. HV₂₅was measured (ASTM E 384-99^E1, Vickers indenter, 50 g load) at a depth of 0.002″ below the surface and was 2018 and 1926 for the samples treated at 1700° and 1500°, respectively, while HV₅₀₀measured at the (unborided) core was 156 and 162, respectively, an improvement of about 12-13%. FIG. 5 is a graph of HV₅₀for borided valve bodies, seats, and a liner, measured across a cross section of a sample prepared to a 1 micron final polish.

EXAMPLE 2

Field Testing of Boronized Valve Seat and Valve Body

Four borided valve bodies and valve seats, with urethane insert, as well as four non-borided valve bodies and valve seats (control), with urethane inserts, were installed on a Continental Emsco DB 550 Duplex mud pump. The pump was run under normal operating conditions for four months, at which point the non-borided parts had to be replaced. The borided parts continued to work effectively.
Other embodiments of the invention will be apparent to those skilled in the art from a consideration of the specification or practice of the invention disclosed herein. It is intended that the specification and examples be considered as exemplary only, with the true scope and spirit of the invention being indicated by the following claims.

Claims

1. A component for use in combination with at least a second component during earth-boring, well completion, or fluid extraction, the component having a surface, at least a first portion of which comprises a borided metallic material, and wherein said first portion does not wear against a metallic surface of the second component during use.

2. The component of claim 1, wherein the component is selected from a component of a mud pump or cement pump.

3. The component of claim 1, wherein the component is selected from a mud pump liner, a valve seat, a valve body, a piston hub, a piston rod and a plunger.

4. The component of claim 1, wherein the component is a DTH hammer bit, fracturing tube, drill bit, radial bearing, thrust bearing, mechanical coupling, wear pad, flow diverter, flow restrictor, impeller, drill pipe, valve, directional drilling assembly, hanger assembly, percussion assembly, nozzle, or core lifter.

5. The component of claim 1, wherein the component is a roller, cam, shaft, or pipe.

6. The component of claim 1, wherein the metallic material is selected from a ferrous metal, non-ferrous metal, ferrous metal alloy, and non-ferrous metal alloy.

7. The component of claim 6, wherein the metallic material is a steel.

8. The component of claim 6, wherein the substantially metallic material is titanium, a titanium alloy, or a chromium alloy.

9. A system for preparing a well for fluid extraction, comprising:

a first component having a surface, at least a first portion of which comprises a borided metallic material; and

a second component having a metallic portion, wherein said first portion does not wear against said metallic portion during use.

10. The system of claim 9, wherein the system comprises a drill and a mud pump.

11. The system of claim 10, further comprising a mud pump liner.

12. The system of claim 9, wherein the system comprises a cement pump.

13. The system of claim 9, wherein the system comprises a fracturing tube.

14. The system of claim 9, wherein the first component is selected from a component of a mud pump or cement pump.

15. The system of claim 9, wherein the first component is selected from a mud pump liner, a valve seat, a valve body, a piston hub, a piston rod, and a plunger.

16. The system of claim 9, wherein the first component is a DTH hammer bit, fracturing tube, drill bit, radial bearing, thrust bearing, mechanical coupling, wear pad, flow diverter, flow restrictor, impeller, drill pipe, valve, directional drilling assembly, hanger assembly, percussion assembly, nozzle, or core lifter.

17. The system of claim 9, wherein the first component is a roller, cam, shaft, or pipe.

18. The system of claim 9, wherein the substantially metallic material is selected from a ferrous metal, non-ferrous metal, ferrous metal alloy, and non-ferrous metal alloy.

19. The system of claim 18, wherein the substantially metallic material is a steel.

20. The system of claim 18, wherein the substantially metallic material is titanium, a titanium alloy, or a chromium alloy.

21. A method of preparing a component for wearing against a material transported during earth-boring, well completion, or fluid extraction, the component having a surface, at least a first portion of which comprises a metallic material, the method comprising:

boriding at least the first portion.

22. The method of claim 21, wherein the component is selected from a component of a mud pump or cement pump.

23. The method of claim 21, wherein the component is selected from a mud pump liner, a valve seat, a valve body, a piston hub, a piston rod, and a plunger.

24. The method of claim 21, wherein the component is a DTH hammer bit, fracturing tube, drill bit, radial bearing, thrust bearing, mechanical coupling, wear pad, flow diverter, flow restrictor, impeller, drill pipe, valve, directional drilling assembly, hanger assembly, percussion assembly, nozzle, or core lifter.

25. The method of claim 21, wherein the component is a roller, cam, shaft, or pipe.

26. The method of claim 21, wherein the component is a fishing tool or sucker rod.

27. The method of claim 26, wherein the fishing tool is a spear, taper tap, or overshot

28. The method of claim 21, wherein the substantially metallic material is selected from a ferrous metal, non-ferrous metal, ferrous metal alloy, and non-ferrous metal alloy.

29. The method of claim 28, wherein the substantially metallic material is a steel.

30. The method of claim 28, wherein the substantially metallic material is titanium, a titanium alloy, or a chromium alloy.

31. A pump liner for use in earth-boring, well completion, or fluid extraction, wherein at least a first portion of an interior surface of the pump liner is borided.

32. The pump liner of claim 31, wherein the pump liner is fabricated from a ferrous metal, non-ferrous metal, ferrous metal alloy, or non-ferrous metal alloy.

33. The pump liner of claim 32, wherein the pump liner is fabricated from titanium, a titanium alloy, or a chromium alloy.

34. A component for use in earth-boring, well completion, or fluid extraction, the component having a surface, at least a first portion of which comprises a borided metallic material, and wherein the component is selected from a mud pump liner, valve seat, a valve body, a piston hub, a piston rod, a plunger, sucker rod, and a fishing tool.

35. The component of claim 34, wherein the fishing tool is a spear, taper tap, or overshot.