Patent Grant
11248420
Not applicable
Not applicable
The present invention relates to an improved swivel stand apparatus for use on oil wells.
SWIVEL RENTAL & SUPPLY, L.L.C. has been issued several patents on equipment that can advantageously be used with the apparatus of the present invention (see U.S. Pat. Nos. 8,793,960, and 9,217,297). The present invention is directed to improved features of its previously patented swivel apparatus.
The following U.S. Patent documents are incorporated herein by reference: U.S. Pat. No. 8,793,960 (issued on 5 Aug. 2014); U.S. Pat. No. 9,217,297 (issued on 22 Dec. 2015); U.S. Pat. No. 9,650,841 (issued on 16 May 2017); and U.S. Patent Application Publication No. US2017/0275952 (issued as U.S. Pat. No. 9,938,778 on 10 Apr. 2018).
Also incorporated herein by reference is all prior art cited in those patent documents and the prior art attached to and/or incorporated by reference in my U.S. Provisional patent application No. 62/634,564, filed 23 Feb. 2018.
The drilling process for oil and gas exploration typically requires the installation of production tubing that extends from the underground oil and gas reservoir to the well surface. This production tubing serves as a conduit for the recovery of the oil and gas from the reservoir. The production tubing is typically placed in a protective pipe liner called a tubular casing. The tubular casing, in descending diameters, extends in many cases to hundreds of feet and often cement is placed within the annulus located between the tubular casing and the well bore to hold the tubular casing in place and to ensure a pressure-tight connection between the well surface and the oil and gas reservoir.
Usually the tubular casing remains within the well bore until it has been determined that no oil or gas reservoirs have been found or the reservoirs have been exhausted. In such cases, the well bore must be plugged and abandoned (P & A) as required by law or convention. When a well bore is plugged and abandoned, the casing tubular is typically removed to a desired or prescribed depth and disposed of in a safe manner.
In other cases, an existing well bore is often utilized to allow the well to be drilled in a different direction. Often in such cases, the drill bit being used to advance the drilling cannot pass through the previously installed tubular casing due to an obstruction. If that occurs, it is necessary to remove the casing tubular to a desired depth before drilling operations can be restarted.
In most wells there are at least four tubular strings, beginning with the largest, upper and outer most conductor pipe, the surface casing, the intermediate tubular and finally the production casing. The removal of the tubular casing when required is often very difficult due to the tremendous weight of the tubular strings and, in some cases, the cement that has been placed around and between the various tubular strings.
The removal of the tubular casing from the well, such as when a well is to be plugged and abandoned, generally begins by first inspecting the well and insuring that the well is inactive and free of any residual gas and that the well is safe to allow for removal of the blowout preventers, well head, and other well equipment that is positioned above the tubing hangers. A safe work platform is then established around the wellhead and associated equipment. That work platform is then used to create a bridge plug within the production tubular at a prescribed depth by applying cement to seal or plug the well casing. The production tubular is then cut at a prescribed depth below the surface using chemical cut, jet cut, mechanical cut or other such rotating cutting tools. The cutting tool is supported on the surface and rotated by a rotary swivel. A lifting device is then attached to the inner most tubular by screwing into or spearing the tubular tubing hanger.
Such lifting devices may be the rig's crane if available and not in use by other drilling operations on the site. The production tubular is then lifted to a desired length, usually approximately forty feet, where slips are set to hold the string, and tongs are used to uncouple the tubular joints. However, in many cases the drill casing tubular cannot be uncoupled in this manner. In the latter case, two diametrically opposing holes are cut in the casing and a bar is then inserted through the holes and the lifting device, such as a crane, is slaked off to allow the bar to rest on top of the well flange. The tubular is then flame cut just above the bar and the initial section of tubular is then removed. In some cases, where cement is present between the tubular strings, it becomes necessary to chip away the cement in order to cut the lifting bar holes. The crane then returns and is attached to the bar thus lifting the tubular string for another length and holes are again cut for a lifting bar. The process described above is then repeated for each tubular string until all the tubulars are removed.
Each incremental section of tubular usually requires operators to cut the casing, usually by torch, and manually drill two holes. The two holes are drilled from each side of the tubular in an attempt to keep them aligned with each other. It is essential that the holes be aligned with each other or large enough so that the bar or rod can be placed through the two holes. As discussed above, raising the tubular requires an extensive amount of force to overcome the resisting forces. Therefore, a stable platform is required. After the various increments of casing tubular are cut and pulled from the well bore, they are disposed of in a prescribed manner. Where holes drilled for the bars are individually and sequentially drilled in each incremental section of casing it is essential that proper tooling be used to maintain alignment. The operators usually drill one side at a time, a slow and tedious process, especially with heavy gauge pipe. In some cases up to two hours is required. The operator is required to drill a second hole that is diametrically opposite the first. In some cases the operator is fortunate enough to get the two holes lined up, but at other times the two holes did not line up and a bar could not be inserted through both holes in which case a torch is used to enlarge at least one of the holes so that the bar could be placed through both holes.
A dual drill system that drills holes from both sides simultaneously, thereby insuring alignment, may be used. Although the time required to drill the holes may be drastically reduced in such cases, a significant amount of time is still required to set up, and to clear, lubricate and repair the drill bits. In addition, a torch is still often used to cut each section of the tubular being removed. Since a torch is used to separate the tubular into reasonable lengths, it has become more prevalent to simply cut the holes with a torch as well. In view of the process described above, a faster and more efficient method is needed to perform these tasks with greater certainty.
In more recent years the P & A operation has included the use of a portable power swivel to assist in cutting casing down hole for removal. Such power swivels are generally portable hydraulic systems used on a well site having multiple well heads and where existing cranes are not always available for the P & A operation. Therefore, a temporary derrick must be erected adjacent the wellhead to be removed and the P & A operation carried out using the power swivel. Such derricks may or may not include a means for raising the well casing. In most cases a simple frame to support well casing cutting tools is sufficient to separate sections of the well casing. Such frames have evolved from a simple “A” frame structure to more complicated wellhead adapted frames having a vertical mast traversable in at least two planes.
However, in most cases the frames are fitted so as to include a power swivel and its cutting tools. However, in many cases such adaptation to an offshore wellhead is not necessary on well sites having multiple well heads. Such sites have very limited space available and therefore the size of the temporary derrick must be restricted. Therefore, a simple skid having a traversable mast to support a plurality of tools is all that is needed. There a power swivel may be one of several tools that may be adapted to the mast, thereby making the skid and mast assembly much more universal.
The present invention includes a swivel stand apparatus that improves my U.S. Pat. No. 8,793,960, including friction-reducing members and a locking mechanism for detachably locking the stand tower or mast to a swivel mounting frame.
It is better to detachably lock the stand tower to the stand horizontal beams using the locking mechanism because it is easier to rig up, especially where it is helpful to hoist the stand tower after the basket of the present invention is hoisted into place (with the locking members, the swivel stand tower can be lowered vertically onto the horizontal beams of the swivel mounting frame rather than laterally slid into place in the overlapping metal plates of the guide as in my U.S. Pat. No. 8,793,960).
The swivel stand of the present invention preferably uses flanged beams (e.g., channel beams) to allow the stand tower to slide back and forth (rather than using overlapping plates as in my U.S. Pat. No. 8,793,960). There are friction-reducing members for facilitating motion between the stand horizontal beams of the swivel mounting frame and the basket flanged beams (preferably attached to each of the stand horizontal beams at least on the bottom that contacts the flanged beams, and preferably on all surfaces that contact the flanged beams). There are friction-reducing members between the stand tower and the stand horizontal beams to help prevent electrolysis and to prevent wear of metal on metal.
The stand horizontal beams preferably have skids attached to the bottom thereof to allow the beams to slide up over the plates in the floor of the upper basket. These skids contact the plates to help stabilize the tower as rotating tools are used, and to help transfer load from the tower to the basket, not just through the flanged beams or C-channels. The stand horizontal beams preferably are attached together with, for example, at least one lateral beam to form a U-shaped base (a swivel mounting frame or skate).
The present invention also includes work baskets, including a modular work basket with multiple interchangeable parts to allow it to be used on the floor of an oil well drilling rig or directly attached to the wellhead. The work basket connects to at least two different bases. The work basket and the bases preferably connect together using legs which are sized so that the basket and bases can only connect in a single orientation (to prevent the base from being connected backwards, for example, to the basket). The work basket preferably has specially configured pipe supports that are used to support vertically positioned pipe sections, which are preferably pivotally attached thereto. Preferably, these allow multiple joints of pipe to be received therein and held in place vertically next to the work basket while operations occur.
There are three preferred basket and support base configurations. In one configuration the work basket is connected to a flange base (about 18-inch high) which can be bolted directly to a wellhead. This first configuration includes a square plate in the opening in the basket floor with a hinged door. Typically in this configuration jacks are not used.
In a second configuration, the upper work basket can be connected to a jack base (preferably about eight feet (8′) wide by ten feet (10′) long by eight feet (8′) high) with a square plate in the opening in the basket floor, the square plate having a round opening for the jack to protrude through.
In a third configuration, the work basket is connected to a flange base (about 18-inch high) which is bolted directly to a wellhead, with an upper level jack platform in the opening in the basket floor. This configuration is typically used when one starts with the first configuration, and then jacks are needed.
The flange base can include preferably a thick base plate (about three inches (3″) thick and about eighteen inches (18″) high).
The jack base preferably has 5th and 6th legs (center supports or braces) to support the upper basket. With these center support braces the basket rests on them for load transfer. The upper work basket is also connected to corner legs of the jack base.
The apparatus of the present invention includes a rotating boom assembly which can advantageously be used with the swivel stands and associated equipment of the present invention. This rotating boom assembly preferably includes roller bearings to allow it to be rotated by a single worker.
The boom can provide a hydraulic arm with at least a 3-foot reach for moving items along the boom. Roller bearings and hydraulic arm together allow one man to do easily which formerly several men did with great effort. This boom arrangement also makes it safer for the workers. The rotating boom assembly is preferably mounted on the upper work basket.
It is better to detachably lock the stand tower or mast to the stand horizontal beams using the locking mechanism because it is easier to rig up, especially where it is helpful to hoist the stand tower or mast after the basket of the present invention is hoisted into place (with the locking members, the swivel stand tower can be lowered vertically onto the horizontal beams of the swivel mounting frame rather than laterally slid into place in the overlapping metal plates of the guide as in my U.S. Pat. No. 8,793,960).
The swivel stand of the present invention preferably uses flanged beams to allow the stand tower to slide back and forth. There are friction-reducing members (e.g., sliders) for facilitating motion between the stand horizontal beams of the swivel mounting frame and the basket flanged beams (preferably attached to each of the stand horizontal beams, at least on the bottom that contacts the beams, and can be on the sides as well. These friction-reducing members, e.g., sliders, can be located on three sides of the beams so that there is no metal-to-metal contact. There can be friction-reducing members between the stand tower and the stand horizontal beams to help prevent electrolysis and to prevent wear of metal on metal.
The stand horizontal beams can have skids attached to the bottom thereof to allow the beams to slide up over the plates in the floor of the basket. These skids contact the plates to help stabilize the tower as rotating tools are used. The stand horizontal beams preferably are attached together with for example at least one lateral beam to form a base in plan or top view (a swivel mounting frame).
There are three possible configurations of a basket and support base:
In one configuration, the work basket is connected to a flange base (about 18-inch high) which is bolted directly to a wellhead, with a square plate in the basket floor with a hinged door—typically in this configuration jacks are not used.
In a second configuration, the work basket is connected to a jack base with a square plate in the basket floor, the square plate having a round opening for the jack to protrude through.
In a third configuration, the work basket is connected to a flange base (about 18-inch high) which is bolted directly to a wellhead, with an upper level jack platform in the square opening in the basket floor. It is preferably sized such that the rectangular upper level fits in and covers the square hole in the basket floor. The upper level jack platform configuration 1 (without the upper level jack platform installed) goes in place of the square plate with a round hole.
In the third configuration, the jack sits on the upper level jack platform, and the upper level jack platform projects slightly above the basket floor, but just a little (about a mm or two) so that the snow-ski-like projections on the bottom of the skate can still ride up onto the upper level jack platform and so that the upper level jack platform does not cause a trip hazard. Having the upper level jack platform project slightly above the basket floor allows force on the platform project through the load transfer cone without being transferred through the basket.
The snow-ski-like projections on the bottom of the skate ride up onto the square plates (all 3—with round open hole, with door, and upper level jack platform with force transfer cone) to help transfer force from the skate to the square plates then to the basket (or in the case of the upper level jack platform with force transfer cone, to the flange base and wellhead below it). Due to the riding up onto the plates, it is helpful to have a friction-reducing slider on top of the skate in the flanged beam or C-channel to reduce friction between the flanged beam or C-channel and the skate when the snow-ski-like projections are over the square plates.
The jack base preferably has 5th and 6th support columns or legs (center supports) to support the basket. These center supports do not have to be mechanically interlocked to the work basket—the basket can just rest on them. The work basket is connected to the corner legs.
There is preferably as well a hydraulic arm with at least a three-foot reach for moving items along the boom. The roller bearings and hydraulic arm together allow one man to do easily which formerly several men did with great effort. This also makes it safer for the workers. The rotating boom assembly is preferably mounted on the work basket.
The present invention preferably includes a flanged beam track with friction-reducing sliders between the track and the swivel mounting frame (for example, made of polytetrafluoroethylene (PTFE, often sold under the trademark Teflon®), but could instead be made of ABS (acrylonitrile butadiene styrene) plastic or PVC (poly(vinyl chloride)) plastic, for example)(The sliders are preferably removable and replaceable after each cut so fouling by metal cuttings is not a problem—the sliders can be removably attached, for example, with screws to, for example, the swivel mounting frame). There is also preferably a friction-reducing slider between the swivel tower and the swivel mounting frame which slides on the track.
Typically, the jack base is used when the basket is used on beams on platforms.
Preferably at least some of the upper legs of the bottom baskets are different lengths to prevent mis-matching of the work basket to the flange base or jack base.
A locking mechanism allows quick connection and removal of the upper assembly to the sliding mast beams.
Solid PTFE (Teflon®) sliders, or skiis, which are easily removed and replaced, are preferably included between the bottom of the top assembly and the flanged beams.
A transfer cone is used upside down (square base up, round apex of cone down) to transfer load from above it directly to well Christmas tree (or blow out preventer BOP) without impacting the basket. This is advantageous because the basket only needs to be robust enough to hold personnel and tools, not the force that is generated by the jacks which rest on the square base of the transfer cone.
One or more embodiments of the swivel stand and basket apparatus of the present invention can rig up in ⅓ of the time that it takes some prior art apparatuses, due to the modular nature of the equipment. The parts relatively easily connect to one another. The work basket is larger than many prior art baskets. The baskets can be used without a swivel stand but usually the swivel stand will be used.
The basket of the present invention is designed to be attached to two bases of the present invention:
A relatively thick flange base (having for example, and preferably, a 3″ thick base plate) about (18″ high); and
A jack base (which can be, for example, preferably about 8′ wide by 10′ long by 8′ high); wherein the 5th and 6th legs (center support braces) of the jack base support the basket, but they are not mechanically connected—the basket just rests on them, and wherein the basket is connected to the corner legs of the jack base, as, for example, shown in the drawings).
In the basket opening, there are typically three items received—a square plate with a hinged door, a square plate with a round opening for jacks, or an upper level jack platform which protrudes through the opening from a flange base to allow the flange base to be used with jacks. The upper level jack platform includes a load transfer member to permit transfer of up to about 150 tons of load from above the basket floor to the flange base without regard for the load capacity of the basket.
For a further understanding of the nature, objects, and advantages of the present invention, reference should be had to the following detailed description, read in conjunction with the following drawings, wherein like reference numerals denote like elements and wherein:
Basket 14 or upper level 14 can optionally attach to either base 11 or 12. Skate or carriage 16 (
Base 11 (
In between each pair of corner columns, 27-30 there can be provided horizontal members 34, 35, 36. These include an upper horizontal member 34, a lower horizontal member 36, and a mid level horizontal member 35 that is in between the members 34, 36. Base 11 has deck 40 and deck opening 41.
A pair of support columns 37, 38 are provided on base 11. Each support column 37, 38 provides for load transfer between basket 14 and base 11. Each support column 37 is in between two corner columns 27, 28, 29 or 30. Columns 27, 28, 29, and 30 of base 11 can have lifting eyes 39. Stab fittings 45 on basket 14 (see
Referring now to the embodiment of
In the third configuration, the jack sits on the upper level jack platform, and the upper level jack platform projects slightly above the basket floor, but preferably just a little (about ¼ inch) so that the upper level jack platform does not cause a trip hazard. Preferably there are about ¼ inch thick flanges on the ends of the square base as shown, and the platform is aligned such that those flanges will help the snow-ski-like projections on the bottom of the skate ride up onto the upper level jack platform (though typically this does not occur). Having the upper level jack platform project slightly above the basket floor allows force on the platform project through the load transfer cone without being transferred through the basket.
Flanged beams or channel beams 54, 56 on basket 14 are generally parallel to one another and provide runways for attaching skate or carriage 16 to platform or basket 14. Beams 54, 56 can be welded to basket 14 at opposed sides of basket 14 (see
A pair of spaced apart lower horizontal beams 72, 74 are connected to platform 14, each spanning between two columns. The beam 72 can span between columns 46, 47. The beam 74 can span between the basket columns 48, 49. Vertical beams 76 span between peripheral beam 62 and lower beam 72. Similarly, vertical beams 78 span between lower horizontal beam 74 and peripheral beam 66. Upon assembly of basket 14 to base 11, stab fittings 45 of basket columns 46, 47, 48, 49 enter the sockets 42 of columns 27, 28, 29, 30 of base 11. Support columns 37, 38 engage the underside of the lower horizontal support beams 72, 74. Load transfer between the lower horizontal beams 72, 74 and the peripheral beams 62, 66 from columns 37, 38 is via vertical beams 76 and 78. Basket 14 can have fork lift tine sockets/tubes 79. Preferably at least some of the upper legs of the bottom or base 11 are different lengths to prevent mismatching of the work basket to the flange base or jack base. For example, three can be one length and the fourth can be 6 inches shorter. The legs of the flange base 12 and the jack base 11 will then have different lengths, with for example three legs of the jack base 11 having one length and a fourth leg being 6 inches longer.
Base 12 (see
Skate or carriage 16 is shown in more detail in
A clamping arrangement is provided by opposed clamps 124, 126. Each clamp 124, 126 is pivotally attached to skate 16 at pivot pins or pivots 128, 130. Locking pins or locks are provided at 132, 134 for locking the clamp 124 or 126 in the clamping position of
Upper level jack platform with load transfer member 250 (see
The bottom of the load transfer cone contacts the flange plate and transfers force to the 3″ flange base then to the wellhead. When properly placed on the flange base, the opening 256 in the upper level jack platform 250 aligns with the opening in the flange base. While referred to herein as a cone, the load transfer member 252 is preferably a cylindrical support 253 with gussets 254 attached thereto and supporting jack platform 251.
Rotating boom assembly 201 (see
The following is a list of parts and materials suitable for use in the present invention.
All measurements disclosed herein are at standard temperature and pressure, at sea level on Earth, unless indicated otherwise. All materials used or intended to be used in a human being are biocompatible, unless indicated otherwise.
The foregoing embodiments are presented by way of example only; the scope of the present invention is to be limited only by the following claims.
This is a continuation of my U.S. patent application Ser. No. 15/904,035, filed 23 Feb. 2018 (issued as U.S. Pat. No. 10,815,735 on 27 Oct. 2020), which claims the benefit of my U.S. provisional patent application No. 62/462,730, filed 23 Feb. 2017, and my U.S. provisional patent application No. 62/634,564, filed 23 Feb. 2018, where are hereby incorporated herein by reference and priority of which is hereby claimed.
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| Entry |
|---|
| Terminator Cut & Pull System Powerpoint, 2013 (15 pages). |
| Express Energy Services Introduces New Technology For Offshore Plug & Abandonment And Decommissioning, http://www.eeslp.com/news/expressenergyservicesintroducesnewtechnologyforoffshoreplugabandomentanddecommissioning/, downloaded May 27, 2015. |
| Express Energy Services—Mechanical Cutter Animation—Video accessed at https://vimeo.com/40967983, indicated to have been uploaded Apr. 24, 2012. Screenshots of the video are submitted. |
| Photographs of prior art basket and swivel stand. |
| Photographs of Vertical Tool Hanger (VTH-02), taken in 2016. |
| Terminator Cut & Pull System Powerpoint with Measurements and Weights for the Terminator System (6 pages). |
| Number | Date | Country | |
|---|---|---|---|
| 62634564 | Feb 2018 | US | |
| 62462730 | Feb 2017 | US |
| Number | Date | Country | |
|---|---|---|---|
| Parent | 15904035 | Feb 2018 | US |
| Child | 17014518 | US |
