WO2001020213A1 - Partial coil-in-coil tubing - Google Patents
Partial coil-in-coil tubing Download PDFInfo
- Publication number
- WO2001020213A1 WO2001020213A1 PCT/US1999/020822 US9920822W WO0120213A1 WO 2001020213 A1 WO2001020213 A1 WO 2001020213A1 US 9920822 W US9920822 W US 9920822W WO 0120213 A1 WO0120213 A1 WO 0120213A1
- Authority
- WO
- WIPO (PCT)
- Prior art keywords
- tubing
- string
- coiled
- seal
- inner tubing
- Prior art date
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Classifications
-
- F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
- F16—ENGINEERING ELEMENTS AND UNITS; GENERAL MEASURES FOR PRODUCING AND MAINTAINING EFFECTIVE FUNCTIONING OF MACHINES OR INSTALLATIONS; THERMAL INSULATION IN GENERAL
- F16L—PIPES; JOINTS OR FITTINGS FOR PIPES; SUPPORTS FOR PIPES, CABLES OR PROTECTIVE TUBING; MEANS FOR THERMAL INSULATION IN GENERAL
- F16L11/00—Hoses, i.e. flexible pipes
- F16L11/14—Hoses, i.e. flexible pipes made of rigid material, e.g. metal or hard plastics
Definitions
- the invention relates to coiled tubing strings, and in particular to at least partial dual tubing strings, including methods for assembling such strings.
- This invention is tangentially related to U.S. Patent No. 5,638,904 - Safeguarded Method and Apparatus for Fluid Communication Using Coiled Tubing, With Application to Drill Stem Testing - Inventors Misselbrook et al.; PCT Application US 97/03563 filed 3/5/97 for Method and Apparatus using Coil- in-Coil Tubing for Well Formation, Treatment, Test and Measurement Operations - Inventors Misselbrook et al; and US SN 08/564,357 entitled Insulated and/or Concentric Coiled Tubing.
- the instant invention relates to apparatus and assembly for at least a partial dual tubing or "coil-in-coil” tubing string, sometimes referred to as PCCT, wherein an inner tubing is sealed within an outer coiled tubing.
- coil-in-coil may be used, the "inner tubing” need not necessarily be “coiled tubing", or “coiled tubing” as it is known or practiced today. Standard “coiled tubing” as the “inner tubing” does afford a practical solution for first embodiments.
- the inner tubing could comprise a liner, for instance.
- partial coil-in-coil strings may have cost advantages.
- a general purpose multi-use partial dual string should have enough dual length to cover the anticipated length of well interval to be serviced.
- the overall length of the PCCT string will be chosen to service a typical depth range of wells in a particular location. But, coiled tubing may be added or removed from the bottom of the outer coiled tubing string to suit wells outside of the standard depth range.
- a full dual tubing string would perform adequately but would be more expensive.
- a partial dual string could be formed by connecting a full dual portion with a single portion. Such a partial dual string could be pre-formed and transported to a job or formed at a job site.
- a key purpose for using an at least partial dual string is to provide a protective barrier at the surface to enable safe pumping of well fluids up or down.
- a dual string has a sealed annulus or the tubings are sealed together, in whole or in part.
- a dual tubing string annulus preferably would be sealed at or proximate a lower end of the inner tubing, and the seal is preferably located across the annulus between the inner and outer coiled tubing, most preferably within the outer coiled tubing.
- any annulus would be narrow, to maximize working space.
- Means can be provided to monitor fluid status, such as fluid flow or pressure, within any annulus formed.
- a pressurized fluid such as nitrogen could be injected, for instance, into the annulus, or existing fluid within an annulus could be pressured up.
- Coiled tubing is commonly utilized in well servicing for working over wells.
- a continuous coiled tubing string is injected into a live well using an associated stuffing box located over the wellhead.
- Many coiled tubing workovers take place under live well conditions.
- Coiled tubing has proven particularly useful when working through production tubing or completion tubing.
- coiled tubing In normal operations coiled tubing is over-pressured vis a vis well pressure. This insures that were any leaks to develop in the tubing, they would result in flow out of the tubing rather than the reverse, which is important for safety reasons. Pressure in the coiled tubing also keeps well fluids from backing up the tubing bore. Well fluids are relegated to the annular space between the coiled tubing and the production tubing or completion tubing. If produced up the annular space outside the coiled tubing, well fluids can be handled in the usual safe manner at a wellhead.
- Fluids pumped down through a coiled tubing string typically enter the tubing at a valve located upon an axle of the reel carrying the string.
- the fluids run through the remaining tubing wound around the reel, over the gooseneck, down the injector, through the stuffing box, through the wellhead and down the wellbore. Any fluids pumped down a coiled tubing string thus may traverse a significant length of tubing on the surface.
- the instant invention anticipates that some live well applications could be more effectively performed with coiled tubing if well fluids were permitted to be circulated up through the tubing rather than up the annulus.
- the annulus outside of the tubing provides a more effective path for pumping down, leaving the bore for reverse circulating up.
- a gravel pack might be more effective if a gravel slurry, were pumped down the broader production tubing - coiled tubing annular region than down the narrower coiled tubing bore.
- Higher circulation rates might be achieved by pumping the slurry down the annulus. This is particularly true because fluid pumped down the bore must pass through a crossover tool near the bottom.
- Coiled tubing pack-off and crossover tools can be expensive, and the narrow flow paths inherent in miniature tools offer potential sites for blockages.
- a potential benefit of the proposed system lies in the elimination of the need for complex combination pack- off and crossover tools. Eliminating coiled tubing crossover tools and their associated packers could lead to improved reliability of operations. The proposed system could also alleviate bridging and lead to improved sand pack uniformity.
- a well cleanout requires raising sand, gravel or particulate matter collected at the bottom of a wellhole. Raising particulate matter, without it settling out, necessitates establishing an upward flow velocity that is a certain multiple of the settling velocity of the particles in the liquid. Additional difficulty and complexity occurs when raising particulate matter in deviated wells. As a result quite high flow rates may be needed to effect a sufficient liquid velocity in an annulus to carry particles up. Sometimes the flow rates required are only achievable using the larger sizes of coiled tubing which can be impractical or else uneconomic.
- a third live well application for a dual coiled tubing string in accordance with the instant invention lies in using potentially readily available natural gas to unload liquid from live wells.
- natural gas When natural gas is available at a wellhead, from either the same or neighboring wells, such gas may be quite cost effective as a gas lift fluid.
- pumping natural gas down through coiled tubing must be protected at the surface above the wellhead. Personnel and the environment must be safeguarded from leaks that could develop in the coil before the gas passes below the wellhead.
- a small hole or crack functions as an atomizer, spraying pressurized fluid from within the tubing to the surroundings above ground.
- a pooling of leaked gas could be ignited by a spark.
- Hydrogen sulfide or the like might be contained within the well fluid, to mention another danger.
- a dual tubing string, or an at least partial coil-in-coil tubing, as taught by the present invention can cost- effectively provide the needed double barrier to permit well fluids to be safely circulated up or down on the surface through coiled tubing as may be particularly suitable in certain operations.
- an inner tubing in a dual string should be at least long enough, taking into account the wells and their intended applications, to extend on the surface from a reel connection through a wellhead during the critical pumping or "reverse circulation" operation.
- the instant invention of an at least partial dual tubing string comprises an inner tubing within an outer coiled tubing for at least an upper portion of the string.
- the inner tubing is equal to or less than 80% of the length of the outer tubing.
- the outside diameter of the inner tubing is greater than or equal to 80% of the inside diameter of the outer tubing.
- the inner tubing is sealed against the outer tubing at at least a lower portion of the inner tubing.
- a seal is structured to permit some longitudinal movement between an end of the inner tubing and the outer tubing.
- the seal is located within the outer tubing.
- a seal may fix, or cooperate with an element that fixes, the relative location of an end portion of the inner tubing with respect to the outer tubing.
- An upset or stop may be attached or formed onto an inner wall of the outer tubing.
- the stop may be positioned to limit longitudinal movement of an end of the inner tubing relative to outer tubing.
- the inner tubing may be inserted such that it is compressed against and biased against the stop within the outer tubing.
- any annulus defined between the inner tubing and the outer tubing is quite narrow.
- the inner tubing could be of the same or of different material as the outer string. Conveniently, the inner tubing could be coiled tubing of slightly smaller diameter.
- Preferred materials for the inner tubing include aluminum, titanium, beryllium-copper, corrosion resistant alloy materials, plastics with or without reinforcement, composite materials and any other suitable material.
- an inner tubing would run at least 1/2 of the length of the outer tubing, and preferably approximately 1/4 to 1/3 of the length of the outer tubing.
- Fluid or pressurized fluid may be inserted in a defined annulus between the tubings and its status or pressure monitored.
- a fluid such as nitrogen gas may be provided in the annulus. Changes in the pressure of this annulus fluid would indicate a leak in either the inner tubing or the outer tubing. In either case the well could be shut in and work stopped to maximize the safety of the crew and the environment.
- a safety check valve may be attached to a lower end of the string.
- the invention further includes a method for assembling partial coil-in-coil or dual tubing.
- a tubing string may be assembled by inserting an upper end of an inner tubing into a lower end of an outer tubing and moving the upper end of the inner tubing to an upper end of the outer tubing.
- This method may include reeling the assembled string onto a first reel and then re-reeling the string onto a second reel.
- An advantage of such method of assembly is that a directional sliding seal may be attached to the lower end of the inner tubing prior to inserting that lower end into the lower end of the outer tubing. This directional seal may slide relatively easily in one direction, e.g. the direction of insertion, but resist sliding and rather vigorously against the inside wall of the outer tubing when the inner tubing is attempted to be moved in the opposite direction.
- the inner tubing may be welded or connected at its lower end to a sealing section, such as a slip mandrel.
- the sealing may be designed to be swaged out, or forced out by a slip, to form a mechanical fixed connection between the tubings. Fluid seals can back up the mechanical connection.
- Another method for assembling partial coil-in-coil tubing may include affixing a stop on an inside wall portion of the outer tubing.
- the stop would be fixed at a location suitable to limit longitudinal motion of an end of an inner tubing within the outer tubing.
- a stop may be readily introduced on to the flat steel strip at the time of manufacture of the outer coiled tubing string.
- a stop could be useful if a fixed seal were to be effected between the inner tubing and outer tubing, or if relative movement between the tubings is to be restricted.
- the inner tubing could be assembled in the outer tubing so as to be compressed against and bias against the stop.
- a length of regular coil and a full coil-in-coil length can be welded or connected or delivered to a job unconnected, including on one reel.
- a single coil and a double coil can be made into one string on a job by manually joining a stringer with a connector as they are run into a well.
- the inner tubing may be a liner glued, secured by adhesive, or fused in place. A liner might even be formed in place within the outer tubing.
- Figure 1 illustrates a partial coil-in-coil tubing string in a well.
- Figures 2 and 2A illustrate a coiled tubing reel and valving associated therewith for coil-in-coil or a dual tubing string.
- FIGS 3A-3D illustrate fixed seal systems.
- Figure 4 illustrates sealing an inner tubing within a coiled tubing string including stops on an inside wall of the tubing string.
- Figures 5 illustrates movable seals for sealing an annulus between an inner tubing and a coiled tubing string proximate an end of the inner tubing.
- Figures 6 illustrates a deformable seal system
- Figures 7A-7C illustrate a safety valve sub appropriate for use at the end of a coiled tubing string.
- Narrow when used herein to refer to a narrow annulus, is intended to refer to a dual tubing or coil-in-coil annulus wherein the OD of an inner tubing is slightly smaller than the ID of an outer tubing. The difference between the OD and ID might be 1/10 th of an inch or even less.
- Lower as used herein in reference to coiled tubing, refers to portions of a string toward a distal end of the string, the end not connected to the reel in use.
- Upper refers to tubing portions proximate a string end connected to the reel in use. A tendency for longitudinal movement of an inner tubing relative to an outer tubing during reeling out and in is discussed below.
- Coiled tubing as known in the art, is coiled upon a truckable reel.
- An upset on a tubing inner surface may be generally referred to as a stop.
- a weld bend is a prime example of such a stop.
- Circulating well fluid through a string includes moving any potentially hazardous well fluid up or down coiled tubing where the fluid traverses tubing portions on the surface, which is where protection afforded by a double tubing or double wall could be important.
- Figure 1 illustrates in general a coiled tubing strings, and in particular a partial coil-in-coil string embodiment, PCCT, inserted in a well.
- Truck T (not shown) carries reel R having string S.
- String S carried on reel R contains, for a portion of its upper length, inner tubing IT within outer tubing OT.
- inner tubing IT extends beneath wellhead WH in wellbore WB.
- Seal SL seals the annulus between inner tubing IT and string S proximate an end of inner tubing IT.
- FIGS illustrates in detail.
- PCCT could be formed by connecting a sealed full dual coil, at SL, with a lower length of single coil.
- the outer diameter of inner tubing IT is only slightly smaller than the inside diameter of outer tubing OT of string S, yielding a narrow annulus.
- a 1 3/16 inch OD inner coiled tubing string might be inserted into an approximately 1 1/2 inch OD outer coiled tubing string.
- considerations of the possible ovality of each tubing should be taken into account, as well as wall thickness and available methods and techniques for insertion.
- the wellbore WB in Figure 1 illustrates production tubing PT within the well together with a coiled tubing string, although not to scale.
- operating coiled tubing through production tubing places a significant constraint on the maximum outside diameter of a string that can be used, in general.
- coiled tubing string S is shown winding from reel R over gooseneck G, through injector head I, through stuffing box SB, through wellhead WH and then downhole.
- Figure 1 also illustrates a safety valve sub SV attached to the bottom of coiled tubing string S.
- a safety valve sub SV attached to the bottom of coiled tubing string S.
- the safety valve is particularly useful when the coiled tubing string is being pulled out of the hole and the end of any inner tubing is reeled up past the wellhead.
- a safety valve sub compliments the functionally of an at least partial dual tubing string.
- FIGS 2 and 2A illustrate valving mechanism systems that can be located on coiled tubing reel R.
- Rotating joint valving mechanisms for normal coiled tubing are known in the art and are indicated but not shown in detail.
- the tubing string reeled on reel R in Figures 2 and 2A is indicated as having outer tubing OT and within it inner tubing IT.
- inner tubing IT could be conveying well fluid WF in accordance with the instant invention, and thus inner tubing IT should extend through the reel to a valve such as a conventional rotating joint valve.
- Outer tubing OT may be terminated at a convenient point on the reel, as at pack- off assembly V.
- Pressurized gas container 26 is illustrated as available for pressuring up annulus 21 between the inner tubing IT and outer tubing OT.
- gage 20 might be pressured up to 500 psi with nitrogen in practice.
- gage 20 would transmit signals to a cab or the like on truck T for convenient readout, or at least be easily visible.
- the operator of truck T could conveniently monitor the pressure on gage 20.
- the inner tubing could be a liner, and not even coiled tubing.
- the liner could define an annular space within the outer tubing or fit against, in whole or in part, the outer tubing wall.
- the liner could be preformed or could actually be formed in place in the first instance within the outer tubing.
- a liner could be fused, glued, or secured by adhesive, in whole or in part, to the outer tubing. Cryogenic methods could be used to shrink a liner during installation. Heat, chemicals or radiation could be used to effect a seal.
- Any seal of an inner tubing be it coiled tubing, liner or otherwise, that significantly increases the stiffness of even a portion of a string may adversely affect string lifetime.
- the choice of seal between the tubing thus, must take into account the effect of the seal on the practical lifetime of the string or it is coiled and uncoiled.
- a seal isolates from fluid communication at least one end of, if not the whole of, an annulus or space formed between an inner tubing and an outer coiled tubing.
- the seal is at least attached proximate to the lower end of the inner tubing and preferably seals against the ID of an outer coiled tubing.
- Seals with low mechanical strength may not anchor themselves against an outer coiled tubing string.
- Methods to reduce or restrict relative movement of the tubings including seals or means that anchor and other elements such as deformable tubes or slips that anchor, may be desirable. It is important, however, that any sealing and/or fixing mechanism retain itself sufficient flexibility to withstand repeated coiling and uncoiling of the string as it spools on and off a reel. Thus, methods to fix or reduce tubing movement should not significantly compromise the bending flexibility of the string and seal.
- a simple internal upset or stop in an outer coiled tubing may be arranged (such as by a miniature weld bead). The inner tubing could then be landed against this upset.
- elastic deformation of the string can help ensure that the inner tubing is always positively engaged against this upset, thus reducing possibility of relative longitudinal movement, at least at the inner tubing distal end.
- seals maybe chosen that can themselves be mechanically deformed to a certain extent while retaining a fixed relationship at their ends to tubing wall surfaces.
- a bellows seal is a prime example. Friction can help limit relative tubing surface-seal movement, while some relative tubing movement is absorbed by deformable portions of a seal.
- One method to seal an at least partial dual tubing string entails drilling a small hole in the outer tubing and either welding, brazing, soldering or gluing the two tubings together.
- the method could include inserting a screw to mechanically restrict movement.
- a hole could be drilled in the outer tubing to allow the injection of a sealing compound after a liner has been inserted.
- a disadvantage of drilling holes is the necessity to ensure that the subsequent repair of the hole eliminates all stress risers which otherwise would limit the plastic fatigue life of a coiled tubing string.
- Spring Energized seals including: Variseal, Canted Spring Seals With and without backup rings
- Self Lubricating Seals including:
- Chemically set seals are possible, in particular as listed below. This type of seal is energized chemically once the seal is set in position. In this way the seal is less likely to be damaged when an inner tubing is installed in an outer coiled tubing. Care should be taken in achieving consistent mixing of appropriate chemical compounds in order to make the seal reliable.
- Heat set seals are possible, in particular as listed below. This type of seal is energized by heating the seal once it is in position. In this way the seal would not be damaged when the inner tubing is installed in the outer coiled tubing. To be practical to use in the field, materials are preferably be selected such that energizing temperatures are moderate.
- cryogenic methods could be utilized to shrink tubing or tubing portions or a seal during insertion, such than a tight fit results when the elements return to ambient temperatures.
- FIG. 4 illustrates upsets or stops ST formed on an inner surface of an outer tubing OT.
- stops ST One convenient means for forming stops ST is to place beads of weld on a strip of metal before it is formed into coiled tubing e.g. before the strip is curled and welded.
- stops ST placed on the inside surface of outer coil OT can thus be used to limit or inhibit substantial longitudinal movement of an end of inner tubing IT within an outer coil OT.
- Such limitation of longitudinal movement could help support fixed seals SL, illustrated as O-rings in Figure 4. between inner tubing IT and outer coil OT. Compression of inner coil IT within outer coil OT, together with a tendency of coil IT to move downward upon deployment, can both assist in biasing inner coil IT against stops ST.
- Fixed seal ports P could be drilled through the outer coil to help effect or establish a seal in practice after assembly, such as with screws, as illustrated in Figure 3B.
- Figure 3A illustrates a seal system between inner tubing IT and outer coiled tubing OT that is mechanically set and fixes the tubings against relative longitudinal movement.
- the seal system does not permit longitudinal movement between inner tubing IT and outer tubing OT after being set.
- the seal system includes deformable tube 44 connected or welded to the bottom of inner tubing IT at well 42. Deformable tube 44 might have a length of 6 to 10 feet. Inserted periodically around deformable tube 44 are elastomeric seals 46. After inner tubing IT is located within outer tubing OT, plug 48 is pressured down the string.
- plug 48 Upon reaching deformable sleeve 44 plug 48 deforms tube 44 plastically outward to compress against and fit against the inner wall of outer tubing OT, pressing thereby the series of elastamer seals 46 tightly against the inner wall of outer tubing OT.
- Figure 3B illustrates a flexible liner sealed with adhesive or melted or sealed by other means against the wall of an outer coiled tubing.
- the seal exists at least at a lower end of the liner and might exist throughout the length of the liner.
- the sealing system illustrated in Figure 3B involves inserting or installing a liner as inner tubing IT.
- the liner is installed with blowout plug 54 at a lower end.
- the blowout plug is attached to the lower end of inner tubing IT by an attachment means 52 of known shear strength. Such means are known in the art.
- the inside of the string could be pressured up to expand the liner.
- Flexible adhesive layer 50 should be activated as by heat, time, temperature or other known means. Once adhesive layer 50 has cured between liner IT and outer tubing OT pressure inside the string could be increased to blow blowout plug 54 out.
- the sealing system includes a hard connection as by welding, bracing, soldering, screws, glue or adhesive.
- 69 is shown as welded at weld 64 to the lower portion of inner tubing IT. Braze, weld, glue, adhesive, or other similar material is inserted in the annulus between the annulus between inner tubing IT and outer tubing OT through port 68.
- FIG. 3D illustrates a slip mechanism and seal.
- Swaging sleeve 74 is swaged by swage piston 76 to force slip mandrel 72 having gripping teeth 75 up against the inner wall of outer tubing OT.
- Inner tubing IT is connected such as by well 73 with slip mandrel 72.
- Seals such as O-ring 71 seal against fluid communication.
- Shear pins 78 hold swaging sleeve 74 in place until sheared by the pressure of swage piston 76.
- Figure 5 illustrates moveable seal means SL as a series of sealing rings, probably O-rings.
- the rings might be structured to offer a better seal when placed in compression in one direction and to slide relatively freely when moved in the opposite direction.
- One method of assembly of inner tubing IT within outer coiled tubing OT, when a directional seal is envisioned, is to load the inner tubing within the outer coil by inserting the upper end of the inner tubing into the lower end of the outer tubing.
- FIG. 6 illustrates a form of flexible or deformable seal.
- Element 80 functions as a bellows seal.
- Element 80 is attached to element 82 which is welded at well 81 to inner tubing IT inside outer tubing OT.
- Bellows seal 83 seals at seal 84 fixedly against the inside wall of outer tubing OT. Relative longitudinal movement of inner tubing IT inside of outer tubing OT will deform bellow seal 83 while leaving the end of bellow seal 83 fixedly sealed at 84 against the inside wall of outer tubing OT.
- a protective sleeve such as sleeve 80 may be used for seal installation and may be pumped out once the seal is in place.
- a device to prevent reverse flow is required.
- a cyclic check valve that can be switched on, off and then on again. It should be low cost, simple and reliable, especially after having sand and debris circulated through it.
- the preferred embodiment is a blowout disc and a ball operated flapper check valve held open by a ported tube. By pressuring up on the CT the blowout disc can be ruptured allowing full reverse circulation. At the end of operations a ball can be circulated to shift the ported tube downwards allowing the check valve to return to full operating mode.
- FIG. 1 A more complex valve arrangement would comprise a multi- position valve that could be de-activated by a ball and re-activated at the end of operations by circulating a second ball.
- FIGs 7A-7C illustrates a typical embodiment of the special check valve that might be used for regular PCCT operations in technically demanding jurisdictions, such as the North Sea.
- Safety valve sub SV might have flapper F biased to close when fluid flows up, or when not pressured back, as is known in the industry. Such flapper F would be biased to close against seal 38 when flow down string S is no longer sufficient to overcome a selected biasing force.
- a further refinement includes a sleeve 34 that can be held in place by a sheer pins 38 and that would bias the flapper continuously open while in place.
- An initial burst disk 35 may be used to seal the string as illustrated in Fig.
- Initial burst disk 35 may be burst by the application of pressure down the string as shown in Fig. 7B.
- ball 32 may be then be sent through the coiled tubing string to land on top of sleeve 34 to shear pins 38.
- the application of pressure down the string subsequently moves sleeve 34 below flapper F in order to allow flapper F to perform as a safety valve.
- flapper F would not close, whether or not fluid pressure is sufficiently strong downhole to overcome the flapper biasing means.
- an at least partial dual tubing string would be deployed down a wellbore and most likely down production tubing.
- the top portion of the tubing string preferably the top one-quarter to one-third of its length, would contain an inner tubing.
- the annulus if any, between the inner tubing and the outer tubing is narrow. Any annulus would be sealed, preferably at least at or proximate an end portion of the inner tubing. If the annulus were sealed anew with each job, the location of the seal may be advantageously positioned per job rather than fixed in the string.
- the seal might be a continuous substance extending through the annulus. The seal might fill any space between the tubings, or the tubings might fit tightly against each other, in whole or in part.
- An annulus, if such exists, between an inner tubing and the outer tubing may be pressured up, such as with a high pressure gas, and the pressure monitored at the surface by suitable equipment.
- well fluid can be safely circulated, either up or down through the coiled tubing.
- the double barrier between the wellhead and a valve on the coiled tubing reel (or the like) provides a safety barrier at the surface against leaks in the coiled tubing string. Leaks in the coiled tubing string below the wellhead go into the annulus and could be controlled by the wellhead.
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- Engineering & Computer Science (AREA)
- General Engineering & Computer Science (AREA)
- Mechanical Engineering (AREA)
- Earth Drilling (AREA)
- Packaging Of Annular Or Rod-Shaped Articles, Wearing Apparel, Cassettes, Or The Like (AREA)
- Gasket Seals (AREA)
- Rigid Pipes And Flexible Pipes (AREA)
- Pens And Brushes (AREA)
- Inks, Pencil-Leads, Or Crayons (AREA)
- Buffer Packaging (AREA)
- Package Frames And Binding Bands (AREA)
- Protection Of Pipes Against Damage, Friction, And Corrosion (AREA)
Abstract
Description
Claims
Priority Applications (7)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
AU61412/99A AU6141299A (en) | 1999-09-10 | 1999-09-10 | Partial coil-in-coil tubing |
PCT/US1999/020822 WO2001020213A1 (en) | 1999-09-10 | 1999-09-10 | Partial coil-in-coil tubing |
GB0207992A GB2372772B (en) | 1999-09-10 | 1999-09-10 | Partial coil-in-coil tubing |
US10/070,788 US6712150B1 (en) | 1999-09-10 | 1999-09-10 | Partial coil-in-coil tubing |
CA002384342A CA2384342C (en) | 1999-09-10 | 1999-09-10 | Partial coil-in-coil tubing |
DK200200303A DK176672B1 (en) | 1999-09-10 | 2002-02-27 | Partial spiral-in-spiral tubing |
NO20021101A NO336759B1 (en) | 1999-09-10 | 2002-03-06 | Partial coiled-in-coiled tubing and method of assembling a protected coiled tubing string |
Applications Claiming Priority (1)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
PCT/US1999/020822 WO2001020213A1 (en) | 1999-09-10 | 1999-09-10 | Partial coil-in-coil tubing |
Related Child Applications (2)
Application Number | Title | Priority Date | Filing Date |
---|---|---|---|
US10/070,788 A-371-Of-International US6712150B1 (en) | 1999-09-10 | 1999-09-10 | Partial coil-in-coil tubing |
US10/356,836 Continuation-In-Part US6834722B2 (en) | 2002-05-01 | 2003-02-03 | Cyclic check valve for coiled tubing |
Publications (1)
Publication Number | Publication Date |
---|---|
WO2001020213A1 true WO2001020213A1 (en) | 2001-03-22 |
Family
ID=22273581
Family Applications (1)
Application Number | Title | Priority Date | Filing Date |
---|---|---|---|
PCT/US1999/020822 WO2001020213A1 (en) | 1999-09-10 | 1999-09-10 | Partial coil-in-coil tubing |
Country Status (6)
Country | Link |
---|---|
AU (1) | AU6141299A (en) |
CA (1) | CA2384342C (en) |
DK (1) | DK176672B1 (en) |
GB (1) | GB2372772B (en) |
NO (1) | NO336759B1 (en) |
WO (1) | WO2001020213A1 (en) |
Cited By (3)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
WO2017078925A1 (en) * | 2015-11-02 | 2017-05-11 | Schlumberger Technology Corporation | Coiled tubing in extended reach wellbores |
WO2019168506A1 (en) * | 2018-02-27 | 2019-09-06 | Halliburton Energy Services, Inc. | Downhole check valve assembly with a frustoconical mandrel |
CN111894517A (en) * | 2020-07-23 | 2020-11-06 | 陈少同 | Underground check valve |
Citations (5)
Publication number | Priority date | Publication date | Assignee | Title |
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US3860037A (en) * | 1973-06-26 | 1975-01-14 | Diamond Shamrock Corp | Tube plugging device |
US4487660A (en) * | 1980-10-31 | 1984-12-11 | Electric Power Research Institute | Multiple wall structure for flexible cable using tubular and spiral corrugations |
US4565351A (en) * | 1984-06-28 | 1986-01-21 | Arnco Corporation | Method for installing cable using an inner duct |
US4629218A (en) * | 1985-01-29 | 1986-12-16 | Quality Tubing, Incorporated | Oilfield coil tubing |
US5992468A (en) * | 1997-07-22 | 1999-11-30 | Camco International Inc. | Cable anchors |
-
1999
- 1999-09-10 GB GB0207992A patent/GB2372772B/en not_active Expired - Fee Related
- 1999-09-10 WO PCT/US1999/020822 patent/WO2001020213A1/en active Application Filing
- 1999-09-10 AU AU61412/99A patent/AU6141299A/en not_active Abandoned
- 1999-09-10 CA CA002384342A patent/CA2384342C/en not_active Expired - Lifetime
-
2002
- 2002-02-27 DK DK200200303A patent/DK176672B1/en not_active IP Right Cessation
- 2002-03-06 NO NO20021101A patent/NO336759B1/en not_active IP Right Cessation
Patent Citations (6)
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US3860037A (en) * | 1973-06-26 | 1975-01-14 | Diamond Shamrock Corp | Tube plugging device |
US4487660A (en) * | 1980-10-31 | 1984-12-11 | Electric Power Research Institute | Multiple wall structure for flexible cable using tubular and spiral corrugations |
US4565351A (en) * | 1984-06-28 | 1986-01-21 | Arnco Corporation | Method for installing cable using an inner duct |
US4565351B1 (en) * | 1984-06-28 | 1992-12-01 | Arnco Corp | |
US4629218A (en) * | 1985-01-29 | 1986-12-16 | Quality Tubing, Incorporated | Oilfield coil tubing |
US5992468A (en) * | 1997-07-22 | 1999-11-30 | Camco International Inc. | Cable anchors |
Cited By (7)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
WO2017078925A1 (en) * | 2015-11-02 | 2017-05-11 | Schlumberger Technology Corporation | Coiled tubing in extended reach wellbores |
US10053926B2 (en) | 2015-11-02 | 2018-08-21 | Schlumberger Technology Corporation | Coiled tubing in extended reach wellbores |
WO2019168506A1 (en) * | 2018-02-27 | 2019-09-06 | Halliburton Energy Services, Inc. | Downhole check valve assembly with a frustoconical mandrel |
GB2582496A (en) * | 2018-02-27 | 2020-09-23 | Halliburton Energy Services Inc | Downhole check valve assembly with a frustoconical mandrel |
US11313189B2 (en) | 2018-02-27 | 2022-04-26 | Halliburton Energy Services, Inc. | Downhole check valve assembly with a frustoconical mandrel |
GB2582496B (en) * | 2018-02-27 | 2022-06-01 | Halliburton Energy Services Inc | Downhole check valve assembly with a frustoconical mandrel |
CN111894517A (en) * | 2020-07-23 | 2020-11-06 | 陈少同 | Underground check valve |
Also Published As
Publication number | Publication date |
---|---|
DK200200303A (en) | 2002-04-15 |
NO20021101L (en) | 2002-05-08 |
CA2384342C (en) | 2009-04-14 |
AU6141299A (en) | 2001-04-17 |
NO20021101D0 (en) | 2002-03-06 |
GB2372772A (en) | 2002-09-04 |
NO336759B1 (en) | 2015-10-26 |
DK176672B1 (en) | 2009-02-09 |
GB2372772B (en) | 2003-09-10 |
CA2384342A1 (en) | 2001-03-22 |
GB0207992D0 (en) | 2002-05-15 |
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