US20220098936A1

US20220098936A1 - Circumferential wear bands for oilfield tubulars

Info

Publication number: US20220098936A1
Application number: US17/423,866
Authority: US
Inventors: Russel Moore
Original assignee: Individual
Current assignee: Individual
Priority date: 2019-01-28
Filing date: 2020-01-27
Publication date: 2022-03-31
Also published as: WO2020154793A1; CA3127104A1

Abstract

A wear band assembly for a pipe string operating inside a casing string includes a fixed cylindrical wear band made from a non-metallic, abrasion-resistant, low-friction material injection-moulded onto a pipe joint or sub incorporated into the pipe string, and optionally having a circumferential wear indicator groove. In an alternative embodiment, the wear band assembly includes a rotatable wear band comprising mating cylindroid sections rotatably disposed within an annular recess formed in a circumferential collar injection-moulded onto the pipe or sub. The rotatable wear band initially projects radially beyond the collar and is rotatable relative to the pipe or sub, allowing the wear band to rotate relative to the casing when in rotational contact therewith, thereby reducing resultant wear to the wear band, and reducing torque in the pipe string due to contact with the casing.

Description

FIELD OF THE DISCLOSURE

The present disclosure relates in general to means for protecting against abrasive wear of a tubular string running inside a larger tubular string, and relates in particular to means for protecting against abrasive wear to tubular strings used to install and remove frac plugs in vertical, horizontal, and deviated oil and gas wells.

BACKGROUND

During a typical “well frac” (i.e., fraccing operation) for an oil or gas well, a frac fluid carrying a proppant (typically sand or ceramic particles) is pumped under high pressure into the subsurface reservoir through perforations in the well casing, in order to fracture the formation and thus increase the flow of formation fluids (e.g., gas and/or crude oil) to the well. Frac plugs are commonly used to isolate individual zones of a well during “plug-and-perf” completion operations in vertical, deviated, and horizontal wells. The frac plugs are set using wireline, coil tubing, or threaded pipe. A one-way internal check valve is closed with a ball while the zone above the plug is fractured. The plug can be run into the well with the ball in place, or the ball can be dropped from surface after the plug has been positioned in the well. The check valve allows free flow of fluids from below the plug after fraccing.
There are many different types of frac plugs, and numerous companies that make them. Some frac plugs have hollow metal button slips that are designed to shatter during milling while they are being drilled out (or “milled out”), as discussed later herein. This feature reduces the metal content of the plugs to decrease mill-out time and debris size when plugs are being removed after completion of fraccing operations for the affected formation zone. One specific example of a frac plug is the “Boss Hog” frac plug manufactured by Downhole Technology, LLC, of Houston, Tex.
The number of frac plugs required for a given fraccing operation is determined by the number of “stage fracs” to be performed on the well. For example, in the Montney Formation of the Western Canadian Sedimentary Basin, there have been wells with as many as 132 stage fracs, and thus as many as 132 plugs for a single well, as each stage is fracced separately. The frac plugs have to be drilled out (or “milled out”) after completion of each stage frac, commonly by means of string of pipe (commonly 2″ or 2½″ nominal diameter) or coil tubing utilizing a mud motor fitted with a milling tool to drill out the plugs. As the pipe (or tubing) string moves through the well, with or without rotation, it will rub against the inner surfaces of the steel casing, causing abrasion and wear to the casing and to the pipe (or tubing) carrying the mud motor. This is particularly true for horizontal and deviated wells where the pipe or tubing string has to bend as it passes through the radiused section where the well profile transitions from vertical to horizontal (or to other non-vertical angular orientations).
It is known to incorporate short tubular components (or “subs”) having an “upset” end (i.e., with a larger outside diameter and radial wall thickness than other portions of the pipe) at intermittent locations in tubing strings so that the upset section will take the brunt of the abrasive wear resulting from sliding and/or rotating contact with an enclosing casing string, with the extra thickness of the upset section ensuring that abrasive wear will not reduce the wall thickness of any portion of the sub to less than the original thickness of the non-upset portion of the sub.
When the upset section has become excessively worn, it can be rebuilt by “hardbanding”, a process that will be familiar to persons skilled in the art, and which involves deposition of wear-wear-resistant hardbanding alloys, such as by means of MIG (metal inert gas) welding or other welding processes. Hardbanding thus provides one way to address or mitigate the problem of abrasive wear to pipe strings moving and rotating within larger tubular strings. However, it is very expensive, both in terms of initial cost of the subs and in terms of the cost of applying remedial hardbanding to worn subs.
The process of drilling out frac plugs in a horizontal well can take a number of days, and due to depth, torque is critical. With very deep drill-outs in a deviated well (e.g., drill-outs near the toe of the horizontal section of the well), the pipe string can get stuck inside the casing (especially in the radiused transition section of the well), and there have been many cases where the pipe has become stuck and was twisted off due to torsional shear induced by rotation applied to the pipe string while it was stuck in the casing. In such cases it will be necessary to fish the sheared-off pipe out of the well, and in the worst case the well may be lost and a new well may have to be drilled.
For the foregoing reasons, there is a need for methods and means for reducing abrasive wear of tubular strings used in frac plug drill-out operations, and also a need for methods and means for reducing torque-induced stresses in such tubular strings, and thus to reduce the risk of the tubular strings becoming stuck in the casing and even shearing off. The present disclosure is directed to these needs.

SUMMARY OF THE DISCLOSURE

In general terms, the present disclosure teaches non-limiting embodiments of circumferential wear bands that can be formed on a steel pipe string, at selected intervals along the length of the pipe string, to protect components of the pipe string from abrasive wear caused by sliding and/or rotating contact with interior surfaces of a larger-diameter tubing string (such as a casing string) within which the pipe string may be moving and/or rotating. The wear bands may be formed on individual lengths (or “joints”) of pipe making up the pipe string, or they can be provided on smaller pipe “subs” incorporated into the pipe string (as discussed above).
The wear bands are preferably made from a non-metallic material suitable for direct application onto steel pipe, such as by injection moulding, and which preferably has relatively high inherent abrasion resistance properties (to maximize the service life of the wear bands before they need to be replaced) and a relatively low coefficient of friction (to promote both longitudinal and rotational sliding of the wear bands relative to inner surfaces of a surrounding casing string so as to minimize induced frictional resistance between the wear bands and the casing string, and thus to minimize torsional and other structural stresses induced in the tubing string by such longitudinal and/or rotational sliding). Non-limiting examples of materials that may be suitable for making or forming wear bands in accordance with the present disclosure include polyketone, HDPE (high-density polyethylene), PEX (cross-linked polyethylene), Fortron® (polyphenylene sulfide), fiberglass, Amodel® (polyphthalamide), Ryton® (polyphenylene sulfide), PE-RT (polyethlene of raised temperature), and UHMW-PE (ultra-high molecular weight polyethylene).
In one embodiment, the wear band is a fixed wear band that is injection-moulded directly onto the exterior surface of the pipe joint or sub. The pipe or sub surfaces onto which the wear band is to be injection-moulded will typically be prepared by wire brushing or other suitable means for removing mill scale and other contaminants from the pipe or sub surface, and thereby to promote a strong bond between the wear band and the pipe surface. In addition, a suitable bonding agent may be applied to the prepared surface prior to the injection-moulding process, as may be desired or appropriate for the materials being used.
Optionally, an annular groove may be formed into the circumferential surface of the wear band to act as a visual wear indicator, to assist well operators in assessing how much reliable service life is remaining for the wear band before it needs to be replaced.
In another embodiment, the wear band is a rotatable wear band provided in the form of multiple mating cylindroid sections (for example, a pair of semi-cylindrical sections) disposed and connected together within an annular recess formed in a circumferential collar that has been injection-moulded onto the pipe or sub in the same general manner as described above with respect to fixed wear band embodiments. The wear band is thus freely rotatable relative to the collar and the pipe (or sub), and thus can rotate relative to the casing when in rotational contact therewith, thereby reducing resultant wear to the wear band itself, and reducing or eliminating the risk of excessive torque developing in the pipe string due to contact with interior surfaces of the casing.
When the rotatable wear band has become worn and needs to be replaced, it is a relatively simple matter to remove the worn multi-piece wear band and replace it with a new one. This ability to replace worn rotatable wear bands makes it possible to greatly and relatively inexpensively extend the service life of a pipe section or sub carrying a rotatable wear band, as compared to fixed wear bands, because the collars moulded onto the pipe or sub to retain the rotatable wear bands will not be subject to abrasive wear in normal service (provided that worn rotatable wear bands are replaced before the risk of contact between the collars and the casing develops).
Wear bands in accordance with the present disclosure will reduce torque and resultant torsional stresses in the pipe string, and will prevent or reduce wear on the pipe string from rubbing against the inside of the casing. The wear bands also will make it easier for the pipe string to slide and rotate within the casing, thus increasing the depth to which the pipe can be inserted into the casing without fear of the pipe becoming stuck in the casing and even being twisted off due to high torque induced in the pipe as a result of being stuck in the casing. As well, the improved ability of the pipe to slide and rotate within the casing string because of the wear bands will reduce the time required for frac plug drill-outs, which is a significant benefit in light of the fact that the cost of these operations can be as much as $20,000 per day or more.
In accordance with the foregoing, in one aspect the present disclosure teaches a wear band assembly comprising a tubular member, plus a generally cylindrical wear band disposed circumferentially around and bonded to a selected portion of the length of the tubular member.
In a second aspect, the present disclosure teaches a wear band assembly comprising a tubular member; a generally cylindrical collar coaxially disposed around, and bonded to, a selected portion of the length of the tubular member, with the collar having an annular wear band retention groove coaxial with the tubular member, and with the wear retention groove having a cylindrical circumferential surface; and a generally cylindrical wear band rotatably and coaxially disposed within the wear band retention groove so as to be coaxially rotatable around the cylindrical circumferential surface of the wear band retention groove.

BRIEF DESCRIPTION OF THE DRAWINGS

Embodiments will now be described with reference to the accompanying Figures, in which numerical references denote like parts, and in which:

FIG. 1 is an isometric view of a pipe sub having an upset end and a circumferential wear band injection-moulded onto the sub, in accordance with a first embodiment covered by the present disclosure.

FIG. 2 is a side view of the sub in FIG. 1.

FIG. 3 is an isometric “free body” view of the wear band shown in FIGS. 1 and 2 (with the pipe sub not shown).

FIG. 4 is an end view of the wear band shown in FIG. 3.

FIG. 4A is a longitudinal cross-section through the wear band in FIG. 3.

FIG. 5 is an isometric view of a pipe sub having an upset end and a circumferential wear band injection-moulded onto the sub, in accordance with a second embodiment covered by the present disclosure, with the wear band having an annular wear indicator groove for.

FIG. 6 is a side view of the sub in FIG. 5.

FIG. 7 is an isometric “free body” view of the wear band shown in FIGS. 5 and 6 (with the pipe sub not shown).

FIG. 8 is an end view of the wear band shown in FIG. 7.

FIG. 8A is a longitudinal cross-section through the wear band in FIG. 7.

FIG. 9 is an isometric view of a pipe having a circumferential collar injection-moulded onto the sub, with a generally cylindrical wear band mounted around and axially retained by the collar so as to be rotatable relative to the collar, in accordance with a third embodiment covered by the present disclosure.

FIG. 10 is a side view of the pipe, collar, and rotatable wear band assembly shown in FIG. 9.

FIG. 10A is a transverse cross-section through the pipe, collar, and rotatable wear band assembly shown in FIG. 10.

FIG. 10B is a longitudinal cross-section through the pipe and collar of the assembly shown in FIG. 10, indicating the annular wear band retention groove in the collar, but not showing the rotatable wear band.

FIG. 11 is an enlarged version of the transverse cross-section in FIG. 10A.

DESCRIPTION

FIGS. 1 to 4A illustrate an embodiment 100 of a wear band assembly comprising a pipe sub 10 having a fixed wear band 110 injection-moulded onto pipe sub 10 in accordance with the present disclosure. Pipe sub 10 is shown as having a double-threaded pin end 12, a box end 14, and an upset section 15, with wear band 110 being formed at a location proximal to upset section 15 and having a greater outer diameter than upset section 15, such that wear band 110 will contact the surfaces of the bore of a casing string in which a pipe string carrying pipe sub 10 is disposed, and thus will prevent upset section 15 and from contacting the casing bore surfaces. However, this represents only one non-limiting example of a tubular member having a wear band 110, and embodiments in accordance with the present disclosure are not limited to or restricted in any way to any particular characteristics of the tubular member carrying wear band 110. Wear bands in accordance with the present disclosure can be formed on other types of tubular members, including conventional joints of pipe having external API tapered threads at each end for connection into a pipe string using conventional internally-threaded cylindrical couplers.
FIGS. 5 to 8A illustrate a wear band assembly 100A comprising a pipe sub 10 having a fixed wear band 110A similar in all respects to wear band 110 in FIGS. 1 to 4A, except that wear band 110A has an annular wear indicator groove 120 as an aid to visual detection of wear on wear band 110A. With the initial radial depth of wear indicator groove 120 being known, accumulated wear to wear band 110A after a given length of time in service can be readily assessed either visually or by measuring the remaining radial depth of groove 120.
Fixed wear bands 110 and 110A are shown herein as having bevelled annular portions at each end, but this is by way of non-limiting example only. In variant embodiments, wear bands 110 and 110A could be of simple cylindrical form (i.e., with a uniform outer diameter) with square-cut ends, to provide just one non-limiting example.
FIGS. 9, 10, 10A, 10B, and 11 illustrate a wear band assembly 200 comprising a pipe section 20 having a circumferential collar 210 injection-moulded onto pipe 20, with collar 210 having an annular wear band retention groove 215 configured to receive and axially retain a generally cylindrical rotatable wear band 220 made up of two semi-cylindrical wear band sections 221, such that wear band 220 is free to rotate within wear band retention groove 215 relative to collar 210 and pipe 20. In the illustrated embodiment, wear band 220 is formed with optional longitudinal debris channels 222 allowing the flow of fluids and debris past wear band assembly 200. (Although not shown in FIGS. 1-8A, fixed wear bands 110 and 110A also could optionally be formed with similar debris channels.)
Wear band sections 221 are provided with fastening means 225 for securely connecting wear band sections 221 to each other to form rotatable wear band 220. FIGS. 9, 10, 10A, 10B, and 11 illustrate fastening means 225 in the form of bolted connections (with the “nut” elements of the bolted connections being provided as female threads formed in bolt holes 223 in wear band sections 221), but this is by way of non-limiting example only, as persons skilled in the art will readily appreciate that functionally effective fastening means for wear band sections 221 can be provided in other forms (for example, snap-on connections, or self-tapping screws) using known technologies, and without departing from the scope of the present disclosure.
Circumferential collar 210 and wear band sections 221 are shown herein as having bevelled annular portions at each end, but this is by way of non-limiting example only. In variant embodiments, collar 210 and wear band sections 221 could be of simple cylindrical form (or semi-cylindrical, in the case rotatable wear bands 220 made up of two wear band sections 221), with square-cut ends. What is important, for purposes of preventing unwanted abrasion and wear on collar 210, and thus maximizing the service life of collar 210, is for at least a portion of the outer cylindrical surface of rotatable wear band 220 to have an initial diameter greater than the largest outer diameter of collar 210, such that only rotatable wear band 220, and not collar 210, will come into contact with inner surfaces of the bore of the casing string in which a tubing string fitted with rotatable wear bands 220 is being used.
Wear band sections 221 of rotatable wear band 220 are illustrated herein without wear indicator grooves like annular groove 120 of fixed wear band 110A. Abrasive wear on wear band sections 221 typically will be readily detectable using collar 210 as a visual comparative reference point. Optionally, however, wear indicator grooves could also be provided in variant embodiments of wear band sections 221.
Wear bands 110 and 110A, circumferential collar 210, and wear band sections 221 of wear band assemblies 200 may be made using any functionally suitable materials, including materials noted in the “Summary” section herein, selected to suit the particular service conditions in which they will be used. Collar 210 and wear band sections 221 of a given wear band assembly 200 may use the same or different materials.
The dimensions of wear bands in accordance with embodiments disclosed herein will typically be a matter of design choice to suit the particular service conditions in which the wear bands will be used. Accordingly, wear bands in accordance with the present disclosure are not limited or restricted to any particular dimensional constraints, such as with respect to axial length or radial thicknesses.
It will be readily appreciated by persons skilled in the art that various modifications to embodiments in accordance with the present disclosure may be devised without departing from the present teachings, including modifications that may use structures or materials later conceived or developed. It is especially to be understood that the scope of the present disclosure should not be limited by or to any particular embodiments described, illustrated, and/or claimed herein, but should be given the broadest interpretation consistent with the disclosure as a whole. It is also to be understood that the substitution of a variant of a claimed element or feature, without any substantial resultant change in functionality, will not constitute a departure from the scope of the disclosure or claims.
In this patent document, any form of the word “comprise” is intended to be understood in a non-limiting sense, meaning that any element or feature following such word is included, but elements or features not specifically mentioned are not excluded. A reference to an element or feature by the indefinite article “a” does not exclude the possibility that more than one such element or feature is present, unless the context clearly requires that there be one and only one such element.
Relational and conformational terms such as (but not limited to) “vertical”, “horizontal”, “cylindrical”, “semi-cylindrical”, and “coaxial” are not intended to denote or require absolute mathematical or geometrical precision. Accordingly, such terms are to be understood as denoting or requiring substantial precision only (e.g., “substantially vertical” or “generally horizontal”) unless the context clearly requires otherwise. In particular, it is to be understood that any reference herein to an element as being “generally cylindrical” is intended to mean that the element in question may have inner and outer diameters that vary along the length of the element.
Any use of any form of any term describing an interaction or connection between elements or features is not meant to limit the interaction to direct interaction between the elements or features in question, but may also extend to indirect interaction between the elements such as through secondary or intermediary structure. Any use of any form of the term “typical” is to be interpreted in the sense of being representative of common usage or practice, and is not to be interpreted as implying essentiality or invariability.

Claims

1. A wear band assembly comprising:

(a) a tubular member;

(b) a generally cylindrical collar coaxially disposed around, and bonded to, a selected portion of the length of the tubular member, wherein the collar has an annular wear band retention groove coaxial with the tubular member, and wherein the wear retention groove has a cylindrical circumferential surface; and

(c) a generally cylindrical wear band rotatably and coaxially disposed within the wear band retention groove so as to be coaxially rotatable around the cylindrical circumferential surface of the wear band retention groove.

2. The wear band assembly as in claim 1 wherein the wear band comprises a plurality of cylindroid wear band sections.

3. The wear band as in claim 2 where the cylindroid wear band sections are removably retained within the wear band retention groove by bolted connections between circumferentially-adjacent cylindroid wear band sections.

4. The wear band as in claim 2 where the cylindroid wear band sections are retained within the wear band retention groove by snap-on connections between circumferentially-adjacent cylindroid wear band sections.

5. The wear band assembly as in claim 1 wherein the cylindrical collar is bonded to the tubular member by injection moulding.

6. The wear band assembly as in claim 1 wherein the cylindrical collar is made from a material selected from the group consisting of polyketone, HDPE (high-density polyethylene), PEX (cross-linked polyethylene), Fortron® (polyphenylene sulfide), fiberglass, Amodel® (polyphthalamide), Ryton® (polyphenylene sulfide), PE-RT (polyethlene of raised temperature), and UHMW-PE (ultra-high molecular weight polyethylene).

7. The wear band assembly as in claim 1 wherein the wear band is made from a material selected from the group consisting of polyketone, HDPE (high-density polyethylene), PEX (cross-linked polyethylene), Fortron® (polyphenylene sulfide), fiberglass, Amodel® (polyphthalamide), Ryton® (polyphenylene sulfide), PE-RT (polyethlene of raised temperature), and UHMW-PE (ultra-high molecular weight polyethylene).

8. The wear band assembly as in claim 1 wherein the tubular member comprises a steel pipe section having an upset end.

9. The wear band assembly as claim 8 wherein the cylindrical collar is located proximal to the upset end of the steel pipe section.

10. The wear band assembly as in claim 8 or claim 9 wherein the outer diameter of the wear band is greater than the outer diameter of the upset end of the steel pipe section.

11. The wear band assembly as in claim 1 wherein the wear band is formed with one or more longitudinal debris channels.

12. A wear band assembly comprising:

(a) a tubular member; and

(b) a generally cylindrical wear band disposed circumferentially around and bonded to a selected portion of the length of the tubular member.

13. The wear band assembly as in claim 12 wherein the wear band has a circumferential wear indicator groove.

14. The wear band assembly as in claim 12 or claim 13 wherein the wear band is bonded to the tubular member by injection moulding.

15. The wear band assembly as in claim 12 wherein the wear band is made from a material selected from the group consisting of polyketone, HDPE (high-density polyethylene), PEX (cross-linked polyethylene), Fortron® (polyphenylene sulfide), fiberglass, Amodel® (polyphthalamide), Ryton® (polyphenylene sulfide), PE-RT (polyethlene of raised temperature), and UHMW-PE (ultra-high molecular weight polyethylene).

16. The wear band assembly as in claim 12 wherein the tubular member comprises a steel pipe section having an upset end.

17. The wear band assembly as claim 12 wherein the wear band is located proximal to the upset end of the steel pipe section.

18. The wear band assembly as in claim 16 or claim 17 wherein the outer diameter of the wear band is greater than the outer diameter of the upset end of the steel pipe section.

19. The wear band assembly as in claim 12 wherein the wear band is formed with one or more longitudinal debris channels.