NO20171541A1 - Dual-walled coiled tubing deployed pump - Google Patents
Dual-walled coiled tubing deployed pump Download PDFInfo
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- NO20171541A1 NO20171541A1 NO20171541A NO20171541A NO20171541A1 NO 20171541 A1 NO20171541 A1 NO 20171541A1 NO 20171541 A NO20171541 A NO 20171541A NO 20171541 A NO20171541 A NO 20171541A NO 20171541 A1 NO20171541 A1 NO 20171541A1
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- Prior art keywords
- coiled tubing
- coiied
- tubing string
- duai
- assembiy
- Prior art date
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- 239000004215 Carbon black (E152) Substances 0.000 claims description 14
- 229930195733 hydrocarbon Natural products 0.000 claims description 14
- 150000002430 hydrocarbons Chemical class 0.000 claims description 13
- 230000000295 complement effect Effects 0.000 claims description 3
- 239000012530 fluid Substances 0.000 description 29
- 230000000712 assembly Effects 0.000 description 9
- 238000000429 assembly Methods 0.000 description 9
- 239000004020 conductor Substances 0.000 description 4
- 229910000831 Steel Inorganic materials 0.000 description 3
- 239000010959 steel Substances 0.000 description 3
- 101150062705 Wipf3 gene Proteins 0.000 description 2
- 230000008901 benefit Effects 0.000 description 2
- 230000015572 biosynthetic process Effects 0.000 description 2
- 239000003112 inhibitor Substances 0.000 description 2
- 238000009434 installation Methods 0.000 description 2
- 210000003734 kidney Anatomy 0.000 description 2
- 239000000314 lubricant Substances 0.000 description 2
- 238000000034 method Methods 0.000 description 2
- 230000000717 retained effect Effects 0.000 description 2
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 description 2
- 238000005299 abrasion Methods 0.000 description 1
- 230000004913 activation Effects 0.000 description 1
- 230000004888 barrier function Effects 0.000 description 1
- 239000011230 binding agent Substances 0.000 description 1
- 238000010276 construction Methods 0.000 description 1
- 238000005260 corrosion Methods 0.000 description 1
- 230000007797 corrosion Effects 0.000 description 1
- 230000009977 dual effect Effects 0.000 description 1
- 125000001183 hydrocarbyl group Chemical group 0.000 description 1
- 238000002347 injection Methods 0.000 description 1
- 239000007924 injection Substances 0.000 description 1
- 239000000463 material Substances 0.000 description 1
- 239000002184 metal Substances 0.000 description 1
- 238000012986 modification Methods 0.000 description 1
- 230000004048 modification Effects 0.000 description 1
- 230000037361 pathway Effects 0.000 description 1
- 238000007665 sagging Methods 0.000 description 1
Classifications
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- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B17/00—Drilling rods or pipes; Flexible drill strings; Kellies; Drill collars; Sucker rods; Cables; Casings; Tubings
- E21B17/003—Drilling rods or pipes; Flexible drill strings; Kellies; Drill collars; Sucker rods; Cables; Casings; Tubings with electrically conducting or insulating means
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B17/00—Drilling rods or pipes; Flexible drill strings; Kellies; Drill collars; Sucker rods; Cables; Casings; Tubings
- E21B17/18—Pipes provided with plural fluid passages
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B17/00—Drilling rods or pipes; Flexible drill strings; Kellies; Drill collars; Sucker rods; Cables; Casings; Tubings
- E21B17/20—Flexible or articulated drilling pipes, e.g. flexible or articulated rods, pipes or cables
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B17/00—Drilling rods or pipes; Flexible drill strings; Kellies; Drill collars; Sucker rods; Cables; Casings; Tubings
- E21B17/20—Flexible or articulated drilling pipes, e.g. flexible or articulated rods, pipes or cables
- E21B17/206—Flexible or articulated drilling pipes, e.g. flexible or articulated rods, pipes or cables with conductors, e.g. electrical, optical
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/12—Methods or apparatus for controlling the flow of the obtained fluid to or in wells
- E21B43/121—Lifting well fluids
- E21B43/128—Adaptation of pump systems with down-hole electric drives
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- F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
- F04—POSITIVE - DISPLACEMENT MACHINES FOR LIQUIDS; PUMPS FOR LIQUIDS OR ELASTIC FLUIDS
- F04D—NON-POSITIVE-DISPLACEMENT PUMPS
- F04D13/00—Pumping installations or systems
- F04D13/02—Units comprising pumps and their driving means
- F04D13/06—Units comprising pumps and their driving means the pump being electrically driven
- F04D13/08—Units comprising pumps and their driving means the pump being electrically driven for submerged use
- F04D13/10—Units comprising pumps and their driving means the pump being electrically driven for submerged use adapted for use in mining bore holes
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- Engineering & Computer Science (AREA)
- Mining & Mineral Resources (AREA)
- Geology (AREA)
- Life Sciences & Earth Sciences (AREA)
- Geochemistry & Mineralogy (AREA)
- Fluid Mechanics (AREA)
- Environmental & Geological Engineering (AREA)
- General Life Sciences & Earth Sciences (AREA)
- Physics & Mathematics (AREA)
- Mechanical Engineering (AREA)
- General Engineering & Computer Science (AREA)
- Rigid Pipes And Flexible Pipes (AREA)
- On-Site Construction Work That Accompanies The Preparation And Application Of Concrete (AREA)
- Medicines Containing Material From Animals Or Micro-Organisms (AREA)
- Medicines That Contain Protein Lipid Enzymes And Other Medicines (AREA)
- Structures Of Non-Positive Displacement Pumps (AREA)
Description
DUAL- WALLED COILED TUBiNG PEPLOYED PUMP
BACKGROUND OF THE 1NVENTION
1. Field of the invention
£0001] The invention reiates generally to the use of strings of coiled tubing to dispose devices, such as electrica! submersible pumps into a welibore.
2. Descrtption of the Related Art
[0002] Electric submersible pumps (ESPs) are used to pump hydrocarbon fluids and/or water from subterranean locations. ESPs require electrica! power to be suppiied to them from surface. A typical ESP assembly inciudes a centrifugal pump that is mounted to an electrica! motor. A power cabfe extends from the surface to the motor of the ESP assembly. Conventionaiiy, when ESPs are run into a wellbore, the power cable is strapped to the outer surface of production tubing sections.
SUMMARY OF THE INVENTION
[0003] The invention provides systems and methods for disposing an ESP, or similar device, into a welibore using running arrangements which incorporate inner and outer coiied tubing strings as weil as a power cable which provides power to the motor of the ESP. in a first described embodiment, a power cable is disposed radially between inner and outer coiled tubing strings. In a second described embodiment, a power eabie is disposed within the inner coiled tubing string. These running arrangements provide flow paihs which aliow for the fiow of produced fluids, in certain embodiments, two flow paths are provided.
[0004] The use of duai-waSied coiled tubing string running assemblies provides the possibility of injecting an ESP into a Sive weil which has pressure at surface. Depending upon the corrosiveness of the welibore environment and the cable location
(La, within the inner coiied tubing string or between the inner and outer coiled tubing strings), tubing of different grades, inciuding Cr16, could be used. With the proper seiection of coiled tubing and ESP components, arrangements constructed in accordance with the present invention provide the potential to run an ESP assembly deeper into a weil than conventional technoiogies permit.
[0005] Production arrangements are described which use dual-walled coiled tubing run ESPs to produce hydrocarbon production fluids from wellbores. Embodiments are described wherein capillary lines are iocated within the dual-walled coiled tubing assembly. The invention encompasses dual-walled coiled tubing assemblies that are used to dispose an electric device (such as an ESP) into a wellbore. Additionally, the invention encompasses hydrocarbon production assemblies that include an ESP as weil as a dual-walled coiied tubing assembly that is used to dispose the ESP into a wellbore.
BRIEF DESCRIFTION OF THE PRAWINGS
|0006] The advantages and further aspects of the invention will be readiiy appreciated by those of ordinary skill in the art as the same becomes better understood by reference to the following detaiied descriptton when considered in conjunction with the accompanying drawings in which fike reference characters designate like or similar elements throughout the several fjgures of the drawing and wherein:
[0007] Figure 1 is a side, cross-sectional view of an exemplary wellbore within which is disposed a dual-walled coiied tubing running arrangement and an ESP assembly in accordance with the present invention.
[0008] Figure 1 a is a side, cross-sectional view of a wellbore within which is disposed an alternative dual-walled coiled tubing running arrangement and ESP assembly.
[00093 Figure 1 b is a side, cross-sectional view of a weilbore within which is disposed a further alternative dual-walled coiied tubing running arrangement and ESP assembiy.
[0010] Figure 2 is a sjde, cross-sectionai view of a first embodiment for a dual-walled coiled tubing running arrangement which might be used with the ESP assembly shown in Figs. 1, 1a or 1b.
[0011] Figure 2a is a side, cross-sectional view of a modified first embodiment for a duai-waiied coiled tubing running arrangement wherein the inner coiled tubing string and power cable are twisted to form a spiral configuration.
[0012] Figure 2b is a side, cross-sectional view of a further modified embodiment for a dual-walled coiled tubing running arrangement wherein the inner coiled tubing string and power cable are twisted to form a spira! configuration.
[0013] Figure 3 is an axial cross-section tåken along lines 3-3 in Figure 2.
[0014] Figure 4 is a side, cross-sectional view of an alternative embodiment for a dual-waiied coiled tubing running arrangement which might be used with the ESP assembly shown in Fig. 1.
[0015} Figure 5 is an axial cross-section tåken along lines 5-5 in Figure 4.
[0016] Figure 6 is a side, cross-sectional view of the lower end of a hydrocarbon production assembly being used to produce gas-impregnated production fluid.
[0017] Figure 7 is an axial cross-sectional view of a duai-wailed coiied tubing assembly containing capiiiary lines in a first exemplary arrangement.
[0018] Figure 8 is an axial cross-sectional view of an exemplary dual-walled coiied tubing assembly containing capiiiary lines in a second exempiary arrangement.
[0019] Figure S is an axial cross-sectional view of an exemplary dual-walled coiied tubing assembiy containing capiiiary lines in a third exemplary arrangement.
[0020] Figure 10 is an axiai cross-sectionai view of an exemplary duai-wailed coiied tubing assembiy containing capiiiary lines in a fourth exemplary arrangement.
PETA1LEP PESCRIPT1QN OF THE PREFERREP EMBODIMENTS
[0021] The term "dual-walled," as used herein, is intended to refer broadly to arrangements wherein an inner tubular string or member is iocated radiafiy within an outer tubular string or member to provide a dual-walled tubing structure. A structure can be dual-walled without regard to whether the inner and outer tubular strings are coaxial or concentric.
[0022] Figure 1 depicts an exempiary wellbore 10 that has been drilled through the earth 12 from the surface 14 down to a hydrocarbon-bearing formation 18. It is desired to pump hydrocarbon fiuids from the formation 16 to the surface 14. It is noted that, while welibore 10 is iiiustrated as a substantially vertical wellbore, it might, in practice, have portions that are inclined or horizontaSiy-oriented. The wellbore 10 is iined with meialiic casing 18 in a manner known in the art.
[0023] In the arrangement shown in Figure 1, an electric submersible pump (ESP) assembly 20 is disposed within the welibore 10 håving been run in by a coiled tubing running arrangement 22. There is no downhole packer. The ESP assembly 20 includes a motor 24 and a fluid pump 26 which is powered by the motor 24. in operatien, production fluid is drawn into fluid inlets 27 of the pump 26 and exits via the top of the pump 26 into the coiied tubing running arrangement 22. Conduit 28 transmits eiectricai power past the pump 26 and to the motor 24. The ESP assembly 20 might aiso incorporate a seai section or other components as is known in the art.
[0024] According to a second exemplary arrangement, which is depicted in Figure 1a, an ESP assembly 20 is disposed within wellbore 10 below a downhole packer 70 and håving been run in by a coiled tubing running arrangement 22. The ESP assembly 20 includes a motor 24 and a fluid pump 26 which is powered by the motor 24. in operatien, production fluid is drawn into fiuid inlets 27 of the pump 26 and exits via the top of the pump into the running arrangement 22 or into the casing annuius 29, or botn. as iliustrated by arrows 25. The electricai conduit 28 transmjts electrica! power through the packer 70 past the pump 26 and to the motor 24. Conduit 28 may contain hydraulic lines and or instrumentation lines as weil as the electricai cable powering the motor 24. The ESP assembiy 20 might aiso incorporate a seal section or other components as ts known in the art.
[0025] Figure 1 b depicts a third exemplary arrangement which includes a downhole packer 70. An ESP assembiy 20 is disposed within the welibore 10 above the downhole packer 70, håving been run in by a duai-wailed coiled tubjng assembiy 22. The ESP assembly 20 includes a motor 24 and a fluid pump 26 which is powered by the motor 24. In operation, production fluid is drawn into the bottom of the packer 70, from there into the bottom of pump 26 and exits via the top of the pump 26 into the annuius 29. in this example, the motor 24 is located above the pump 26. Electricai power is suppiied to the motor 24 directiy via the dual-walled coiled tubing assembiy 22. The ESP assembly 20 might also incorporate a seal section or other components as is known in the art. it is noted that there may be other arrangements depicting different locations of the motor 24 relative to the pump 26 and either of these reiative to the packer 70. it is also noted that there may be additional combinations of production fiow paths available within or outside the dual-walled coiled tubing assembly 22.
[0026] Figures 2 and 3 iiiustrate a first embodiment for a dual-walled coiled tubing assembly 30 which might be used for the coiied tubing running arrangement 22. The duai-wailed coiied tubing assembly 30 inciudes an inner coiied tubing string 32 and an outer coiied tubing string 34 which radialiy surrounds the inner coiied tubing string 32. The inner coiied tubing string 32 defines an inner coiied tubing centrai axial passage 36 along its iength. The outer coiied tubing string 34 also defines an outer coiied tubing centrai axiai passage 38 along its iength. Exemplary sizes for the inner and outer coiled tubing strings 32, 34 would be: 1.25" O.D. x 0.125" wail thickness for the inner coiled tubing string 32 and 2.375" O.D, x 0.156" wail thickness for the outer coiied tubing string 34, However, these dimensjons are exempiary only, and other sizes and dimensions might be used. The inner and outer coiied tubing strings 32, 34 are normaily connected together mechanicaiiy at surface and downhole ends and both wouid be hung off from the weiihead. Therefore. both strings 32, 34 may aid in supporting the weight of the ESP assembly 20 as wel! as the inner and outer coiled tubing strings 32, 34 and power cable 40.
|0027] A power cabie 40 is disposed radialiy between the inner and outer coiled tubing strings 32 and 34. The depicted power cable 40 has three electricai conductors 42 contained within an insulating sheath 44. The power cable 40 may contain other elements, such as a gas barrier, a jacket or armor, as generally known in the art. Aitbough three power conductors 42 are depicted and are typicai, there may be more or fewer than three depending upon the requirements for downhole power and controi. Referring to Figure 3, it can be seen that the power cable 40 preferably has a generally kidney-shaped or oblong, curved cross-sectional area. This cross-sectional shape permits the cable 40 to fit between the inner and outer coiled tubing strings 32, 34. The side surface 41 of the cable 40 which abuts the inner coiled tubing string 32 is concave and curved in a manner to be generally complementary to the outer surface of the inner coiied tubing string 32. The opposite side surface 43 of the cable 40 is convex and curved in a manner to be generaiiy complementary to the inner surface of the outer coiied tubing string 34. It should be noted that the cable 40 need not necessarily have a kidney shape, but may, if desired, be round, rectangular or have other cross-sectional shapes. The cable 40 may be built flat or installed flat to bend somewhat during installation to substantially match the outer contour of the inner coiled tubing string 32. Aitematively, the cabie 40 may become bent into a curved or kidney shape due to the ciamping forces of straps 46. Friction between the cabie 40/inner coiied tubing string 32 and the outer coiled tubing string 34 wiii help transmit a portion of the weight of the cable 40 and ESP assembly 20 to the outer coiled tubing string 34>
[0028] Flexible straps 46 are used to secure the cable 40 to the inner coiied tubing string 32. The term "strap" is used nere to denote any form of tensile or compressive fastener, such as a cabie, rope, tie, binder, ciamp and the like. The straps 46 may be secured about the cable 40 and inner coiied tubing string 32 by tightening, tying, iatching, boiting or in other ways known in the art. The straps 46 enciose both the cabie 40 and inner coiled tubing string 32. When the dual-walled coiied tubing assembly 30 is assembled, an axiai fiuid flowpath 48 is defined within the outer coiled tubing string 34. In the depicted assembly 30, the central axial passage 36 provides a first axiai fluid fiowpath while the axial fluid flowpath 48 serves a second axial fluid flowpath. The presence of two, separate axiai fiuid flowpaths within a singie assembiy 30 provides the advantage of aliowing two separate streams of fluid to be transmitted along the assembly 30, Fluids might be transmitted uphole as a resuit of the ESP pump 26 or transmitted downhole in instances wherein one of the flow paths is being used to inject specialized fluids, which might include scaie or asphaitene inhibitors.
[0029] It is noted that the inner coiied tubing string 32 is shown as offset from the center of the outer coiled tubing string 34 due to the presence of the cable 40. As iiiustrated in Fig. 2a, the cabie 40 and inner coiled tubing string 32 are preferabiy twisted along their iength to provide a spiral configuration. An alternative embodiment is depicted in Fig. 2b wherein the cable 40 is spiraled around the inner coiied tubing string 32. The invéntors have determined thatthese spiral configurations are desirable since they distribute the stresses on the cabie 40 more uniformiy as the duai-wailed coiled tubing assembiy 30 is spooled onto and off of a reel. it should be appreciated that, in alternative embodiments, the coiied tubing strings 32, 34 may be arranged concentrically rather than håving offset centers.
[0030] The duai-wailed coiled tubing assembly 30 may be assembied by first disposing the cable 40 in parallel contact with the inner coiied tubing string 32 and then affixing the cable 40 to the inner coiled tubing string 32 with straps 42. Preferabiy, the straps 42 are used tp affix the cable 40 to the inner coiied tubing string 32 in appropriate spaced intervals which are sufficient to affix the cable 40 to the inner coiled tubing string 32 without permitting a large degree of sagging of the cable 40 and to ensure that the cable weight is held uniformiy by the inner coiled tubing string 32 in order to prevent breakage of the cable 40. Thereafter, the inner coiled tubing string 32 and affixed cabie 40 are disposed into the outer coiied tubing string 34. This may be done verticaliy white the outer coiied tubing string 34 is hanging in a weii. Alternatively, it may be done horizontaily with the outer coiied tubing string 34 stretched out and with the inner coiied tubing string 32 and affixed cable 40 either pushed or puiled into the outer coiled tubing string 34. Metal-to-meta! lubricants can be used to reduce the contact friction and ease the installation. More typicaily, the cabie 40 can be fastened to the inner coiled tubing string 32 as the inner coiled tubing string 32 is disposed into the outer coiled tubing string 34. As the cabie 40 is affixed to the inner coiled tubing string 32, both are disposed into the outer coiied tubing string 34. This may be done vérticaliy as the outer coiied tubing string 34 is hanging in a weil. Alternativeiy, it may be done horizontally with the outer coiled tubing string 34 stretched out and with the inner coiied tubing string 32 either pushed or puited into the outer coiled tubing string 34, taking the cabie 40 aiong with it. Again, métai-to-meta! iubricants can be used to reduce the contact friction and ease instaiiation.
[0031] An assembied dual-walied coiied tubing assembiy 30 can be wound onto a coiied tubing reei of a type known in the art for retaining spools of coiled tubing and transported to a weil site for use. An ESP assembiy, such as ESP assembly 20 is then affixed to the coiled tubing assembiy 30 and run into the wellbore in conventionai fashion.
[0032] A further method of injecting cable through a coiied tubing string wouid be to use a water-based metai-on-metal lubricant with a iow coefficient of friction, such as EasyReach™ iubricant, that will permit ionger lengths of cables and coiied tubing strings to be disposed within surrounding coiled tubing strings. Modeiing of these lengths couid be performed taking into account coiled tubing sizes and cabie sizes and using suitabie software designed for design and planning for coiled tubing operaticns.
[0033] Figures 4-5 iliustrate an alternative embodiment for a dual-walied coiied tubing assembiy 50 which might be used for the coiled tubing running arrangement 22. The duai-wailed coiied tubing assembly 50 includes an inner coiled tubing string
32 and an outer coiled tubing string 34. Power cable 40' is disposed within the centrai axial passage 36 of the inner coiled tubing string 32. Power cable 40' preferabiy has a circular cross-section and is shaped and sizéd to fit tightly within the central axiai passage 36 of the inner coiied tubing string 32, To the extent that there is a radial gap 51 between the power cabie 40' and the inner coiled tubing string 32, this gap 51 may be used as a second and separate flow path to transmit fluid through the dual-walled coiled tubing assembiy 50. Alternativeiy, power cabie 40' may have a non-circuiar cross-section or may not fit tightty within the central axial passage 36 of the inner coiied tubing string 32. The power cabie 40<!>may fit ioosely and rély upon the contact friction of its spiraied shape within the inner coiied tubing string 32 to support its weight. Aiso, the power cable 40' may fit ioosely and be supported at regular intervals by support damps attached to the cable 40'. In these situations, there could be fluid flow past the cabie 40'.
[0034] The duai-wailed coiled tubing assembly 50 may be assembied by first disposing the cable 40' into the central axial passage 36 of the inner coiled tubing string 32. This may be done verticaily by lowering the cable 40' into the inner coiied tubing string 32 whiie it is hanging verticaily in a weil. Alternativeiy, it may be done horizontally with the inner coiied tubing string 32 stretched out and with the cable 40' pulied into the inner coiied tubing string 32. Once more, metal-to-metai iubricants can be used to reduce the contact friction and ease instaiiation. The cable 40' may aiso be piaced into the inner coiied tubing string 32 while the inner coiled tubing string 32 is being manufactured. The inner coiled tubing string 32 and cable 40' are then inserted into the outer coiied tubing string 34. These two previous steps may be reversed. An assembied dual-walled coiled tubing assembiy 50 can be wound onto a coiled tubing reel of a type known in the art for retaining spools of coiled tubing and transported to a weil site for use. An ESP assembiy, such as ESP assembly 20 is then affixed to the coiled tubing assembly 50 and run into the wellbore 10.
[0035] The inventars believe that duai-wailed coiled tubing assemblies constructed in accordance with the present invention are advantageous for running ESPs into weilbores. The cable 40 is pr<p>tected from damage since it is contained within the protection of the outer coiied tubing string 34. Such damage has been known to occur as a resuit of welibore debris or disposai of the cable through deviated or horizonta! welibore portions. In some constructions, dual fluid fiowpaths are avaiiabie for fiow of fluid along the assembiy. Additionally, disposing the cable within the outer coiied tubing string 34 permits a standard packer to be set in the wellbore without the need for a speciaiized arrangement håving a bypass to allow a separate cable to be disposed through the packer. The various fluid fiowpaths provided by the dual-walied coiled tubing assemblies ( le., 30, 50) of the present invention might aiso provide one or more pressurized paths for use in downhole activation schemes in which a port is opened or cbsed or a tooi, such as a packer is activated.
[0036] Figure 6 iilustrates an exemplary production arrangement which incorporates a dual-walled coiied tubing assembly in accordance with the present invention and which is being used to produce gas-impregnated production fluid. A production assembly 80 includes duai-wailed coiled tubing assembly 30 wherein duai fluid fiowpaths are provided. An ESP assembly 20 is affixed to the duai-wailed coiled tubing assembly 30 and includes a motor section 24, pump section 26 and a gas separator section 29 of a type known in the art. First and second bypass conduits 62 and 64 extend from the gas separator section 29 past the motor section 24 and enter the dual-walied coiled tubing assembly 30. The bypass conduits 62, 64 are shown in Fig 8 to be iocated externa! to the ESP assembly 20 but may, more typicaiiy, be located intemaily within the ESP assembly 20. During operation, the gas separator section 29 separates gas from the raw feed of gas-impregnated hydrocarbon production fluid. In particuiar, fiow (tndicated by arrow 66} from the first bypass conduit 62 is directed into axiai fiuid flowpath 48. The remaining hydrocarbon production fiuid is directed through second bypass conduit 64 (arrow 68) into axiai fiuid flowpath 36. The duai-waiied coiied tubing assembiy 30 is shown passing through a packer 70. Because in this example the power cabie 40 is retained within the outer coiled tubing string 34, a conventionai packer 70 may be used without the need for a device that aiiows for a separate pass-through for the cable 40.
[0037] An arrangement which the inventars believe wouid be desirable for certain production situations wouid be an arrangement similar to that depicted in Fig, 1 with hydrocarbon fiow up one fiow path. A second arrangement which the inventars believe wouid be desirable for certain production situations wouid be an arrangement similar to that shown in Fig. 1a with fiuid flow going up one flow path and with the outer coil casing annuius isolated by the packer 70. Both of these arrangements become possible for instaiiation into live weils due to the abiJjty to seal around the outer coiied tubing string 34 using conventionai coiled tubing running equipment. This removes the possibility of weil damage resuiting from håving to kili the weil during conventionai tubing instaiiation. The inventars believe that using duai-wailed coiled tubing assemblies with conventionai equipment improves the speed of instaiiation of the ESP as opposed to conventionai tubing, thereby minimizing down time, lost production time and reducing cost,
[0038] Figures 7, 8 and 9 iilustrate exempiary placements for capiiiary lines within duai-wailed coiied tubing assemblies in accordance with the present invention. Capiiiary iines may be used to provide hydrauiic motive force to actuate vaives or to inflate or release certain hydrauiic downhole equipment. Alternativeiy, capiiiary lines can be used to provide conduits to inject specialized fluids into the dual-walied tubing assembiy 30 or 50 at depth. These speciaiized fluids may include scaie or asphaltene inhibitors, in further embodiments, capiiiary lines are instrumentation Hnes which can, for example, be used to monitor downhole temperatures or pressures among other downhole parameters. In further embodiments, high strength steel cables {or other material) can be instalied within the ESP bundle, their purpose being to carry some of the ESP cabie weight in each described embodiment, capiiiary iines are retained radialiy inside of the outer coiled tubing string, thereby providing protection from damage for the capiiiary lines.
[0039] Figure 7 depicts a first exempiary dual-walled coiled tubing assembiy 72 which is similar in most respects to the dual-walled coiied tubing assembly 30 described previousiy. The duai-wailed coiied tubing assembly 72 includes an inner coiied tubing string 32 and an outer coiied tubing string 34 as weil as power cabie 40. Capiiiary lines 74 are disposed within the outer coiled tubing centrai axial pathway 38 alongside the inner coiied tubing string 32 and the cable 40. Straps 46 secure the cabie 40 and the capiiiary lines 74 to the inner coiled tubing string 32.
[0040] Figure 8 iliustrates an alternative exempiary dual-walled coiled tubing assembiy 76. The duai-wailed coiled tubing assembly 76 inciudes an inner coiied tubing string 32 and an outer coiied tubing string 34 as weii as power cabie 40a. Capiiiary lines 74 are disposed within the power cable 40a alongside the conductors 42.
[0041] Figure 9 depicts a further alternative exempiary dual-walled coiied tubing assembly 78 in accordance with the present invention. The dual-walled coiied tubing assembly 78 is simiiar in many respects to the dual-walied coiled tubing assembly 50 described previousiy. The dual-walled coiied tubing assembiy 78 inciudes inner coiied tubing string 32 and an outer coiied tubing string 34. Power cabie 40' is disposed within the inner coiied tubing string central axial passage 36. Capiiiary lines 74 are disposed radialiy between inner coiied tubing string 32 and outer coiied tubing string 34. Straps 46 secure the capiiiary lines 74 to the inner coiled tubing string 32. A fluid fiow path 48 defined within the duai-wailed coiied tubing assembly 78.
[0042] Figure 10 depicts a further alternative exemplary dual-walled coiled tubing assembiy 80 which is similar in many respects to the duai-walied coiled tubing assembly 50 described previousiy. The dual-walled coiled tubing assembiy 80 inciudes inner coiled tubing string 32 and outer coiied tubing string 34. Power cabie 40' is disposed within the inner coiied tubing string 32 centrai axial passage 36. Capiiiary lines 74 are disposed within the power cable 40' alongside the conductor 42. A fiuid fiow path 48 is defined within the duai-coiled tubing assembiy 80. Where there are muitipie capiiiary iines 74, at least first and second fluid injection paths are provided within the outer coiied tubing string 34 by the muitipie capiiiary lines.
[0043] The use of dual-walied coiled tubing assemblies, such as assemblies 30, 50 described herein, provide the possibiiity of injecting an ESP assembly 20 into a live welibore 10 which is under pressure from surface 14. Because the power cable 40740740a is contained within the outer coiied tubing string 34, it is mechanicaily protected from damage due to friction or abrasion with a surrounding casing or other objects or surfaces during run-in. ESPs run on standard coiied tubing or on regular tubing, where the power cabie is strapped to the outside of the tubing, the ESP assembiy cannot normaiiy be run into live weils since there is currentiy not an effective way to seal around the tubing and cable during running in. Therefore, the pressure at surface cannot be contained. In order to run into a live wellbore, in one embodiment, the system wouid be seaied into a downhole packer and fiuid produced up the dual-walied coiled tubing assembly.
[0044] Depending upon the corrosiveness of the weilbore environment into which the ESP 20 wiii be run, and the location of the power cabie 40 or 40740a, coiied tubing of different grades, inciuding Cr16 grade stainiess steel, could be used. For exampie, depending upon downhoie conditions, the inner and outer coiled tubing strings 32, 34 may be made of different grades of steel, thereby maximizing their resistance to corrosion.
[0045] The foregoing description is directed to particuiar embodiments of the present invention for the purpose of iliustration and expianation. It will be apparent, however, to one skiiled in the art that many modifications and changes to the embodiment set fortn above are possible without departing from the scope and the spirit of the invention.
Claims (15)
1. A duai-wailed coiled tubing assembiy to dispose an eiectric submersible pump (20) into a welibore, the duai-wailed coiied tubing assemblycharacterized by: an innér coiled tubing string (32) defining an inner coiled tubing central axial passageway (36) along its Iength; an outer coiied tubing string (34) radiaily surrounding the inner coiled tubing string, the outer coiled tubing string defining an outer coiled tubing string central axiai passage (38) along its Iength; and a power cabie (40) to provide electric power to the electric submersible pump, the power cabie being disposed within the outer coiled tubing string central axiai passage,
2. The duai-wailed coiied tubing assembly of claim 1 wherein the power cable (40) is further disposed within the inner coiled tubing centrai axial passageway (36).
3. The duai-wailed coiied tubing assembly of claim 1 wherein the power cabie (40) is disposed radiaily between the inner coiled tubing string (32) and the outer coiied tubing string (34).
4. The duai-wailed coiied tubing assembiy of claim 1 furthercharacterized byone or more capiiiary lines (74) disposed within the outer coiled tubing string (34).
5. The duai-wailed coiled tubing assembly of claim 4 wherein the one or more capiiiary fines (74) is/are located radiaily between the inner coiled tubing string (32) and the outer coiied tubing string (34).
6. The duai-wailed coiled tubing assembiy of claim 4 wherein the one or more capiiiary lines (74) is/are located radiaily within the inner coiled tubing string (32).
7. The duai-waifed coiled tubing assembiy of claim 4 wherein the one or more capiiiary lines (74) is/are located within the power cable (40).
8. The duai-waifed coiied tubing assembiy of claim 1 furthercharacterized byseparate first and second fiuid flow paths (36,48) defined within the outer coiied tubing string (34).
9. The duai-wailed coiled tubing assembiy of claim 1 furthercharacterized byat ieast one strap (46) securing the power cabie (40) to the inner coiied tubing string (32),
10. The dual-waiied coiled tubing assembiy of claim 1 wherein the electric submersible pump (20) inciudes a pump section (26) and a motor section (24).
11. The dual-walied coiled tubing assembly of claim 1 wherein the power cable (40) presents an axial cross-section håving;
a first side surface (41) that is concave and shaped to be generaiiy compiementary to an outer radial surface of the inner coiied tubing string (32); and
a second side surface (43) that is convex and shaped to be generally complementary to an inner radial surface of the outer coiled tubing string (34).
12. A hydrocarbon production assembly to produce hydrocarbon fiuid from a wellbore, the production assembly beingcharacterized by: an eiectric submersible pump (20); a dual-waiied coiied tubing assembly (22) to dispose the eiectric submersible pump into the weilbore, the duai-wailed coiied tubing assembly comprising: an inner coiled tubing string (32) defining an inner coiled tubing central axiai passageway (36) along its Iength; an outer coiled tubing string (34) radialiy surrounding the inner coiled tubing string, the outer coiied tubing string defining an outer coiied tubing string central axiai passage (38) along its Iength; and a power cable (40) to provide eiectric power to the eiectric submersible pump, the power cable being disposed within the outer coiled tubing string central axiai passage.
13. The hydrocarbon production assembiy of claim 12 wherein the power cabie (40) is further disposed within the inner coiled tubing central axial passageway (36).
14. The hydrocarbon production assembiy of claim 12 wherein the power cabie (40) is disposed radiaily between the inner coiied tubing string (32) and the outer coiled tubing string (34).
15. The hydrocarbon production assembiy of ciaim 12 further comprising one or more capiiiary fines (74) disposed within the outer coiied tubing string (34).
Applications Claiming Priority (2)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| US14/635,569 US20160258231A1 (en) | 2015-03-02 | 2015-03-02 | Dual-Walled Coiled Tubing Deployed Pump |
| PCT/US2016/019899 WO2016140893A1 (en) | 2015-03-02 | 2016-02-26 | Dual-walled coiled tubing deployed pump |
Publications (1)
| Publication Number | Publication Date |
|---|---|
| NO20171541A1 true NO20171541A1 (en) | 2017-09-27 |
Family
ID=56848473
Family Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| NO20171541A NO20171541A1 (en) | 2015-03-02 | 2017-09-27 | Dual-walled coiled tubing deployed pump |
Country Status (4)
| Country | Link |
|---|---|
| US (1) | US20160258231A1 (en) |
| GB (1) | GB2552756A (en) |
| NO (1) | NO20171541A1 (en) |
| WO (1) | WO2016140893A1 (en) |
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| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| AU2013100271B4 (en) * | 2012-12-20 | 2013-10-10 | Reelsafe Pty Ltd | Entwined Pipes |
| WO2017122025A1 (en) * | 2016-01-13 | 2017-07-20 | Zilift Holdings Limited | Method and apparatus for deploying wellbore pump on coiled tubing |
| WO2018194927A1 (en) * | 2017-04-17 | 2018-10-25 | Baker Hughes, A Ge Company, Llc | Dual-walled coiled tubing with downhole flow actuated pump |
| AU2018304477C1 (en) * | 2017-07-21 | 2021-09-23 | Forum Us, Inc. | Apparatus and method for regulating flow from a geological formation |
| US10753166B2 (en) * | 2017-10-06 | 2020-08-25 | Baker Hughes, A Ge Company, Llc | Load reduction device and method for reducing load on power cable coiled tubing |
| US10822942B2 (en) * | 2018-02-13 | 2020-11-03 | Baker Hughes, A Ge Company, Llc | Telemetry system including a super conductor for a resource exploration and recovery system |
| GB201816857D0 (en) | 2018-10-16 | 2018-11-28 | Coilhose As | Well intervention apparatus and method |
| CA3120342A1 (en) * | 2019-03-07 | 2020-09-10 | Halliburton Energy Services, Inc. | Reinforced power cable for electric artificial lift system |
| CA3153250A1 (en) * | 2019-09-03 | 2021-03-11 | Bradley Matlack | Cables for cable deployed electric submersible pumps |
| US11008848B1 (en) | 2019-11-08 | 2021-05-18 | Forum Us, Inc. | Apparatus and methods for regulating flow from a geological formation |
| US11828145B2 (en) * | 2021-10-27 | 2023-11-28 | Saudi Arabian Oil Company | Electrical submersible pump for a wellbore |
Family Cites Families (19)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| US679056A (en) * | 1901-04-23 | 1901-07-23 | Holzman Brothers | Machine for cutting cloth. |
| US4336415A (en) * | 1980-05-16 | 1982-06-22 | Walling John B | Flexible production tubing |
| US5269377A (en) * | 1992-11-25 | 1993-12-14 | Baker Hughes Incorporated | Coil tubing supported electrical submersible pump |
| AU3277495A (en) * | 1995-07-25 | 1997-02-26 | Downhole Systems Technology Canada | Safeguarded method and apparatus for fluid communication usig coiled tubing, with application to drill stem testing |
| US6143988A (en) * | 1997-05-23 | 2000-11-07 | Baker Hughes Incorporated | Coiled tubing supported electrical cable having indentations |
| US6179056B1 (en) * | 1998-02-04 | 2001-01-30 | Ypf International, Ltd. | Artificial lift, concentric tubing production system for wells and method of using same |
| US6298917B1 (en) * | 1998-08-03 | 2001-10-09 | Camco International, Inc. | Coiled tubing system for combination with a submergible pump |
| GB2345199B (en) * | 1998-12-22 | 2003-06-04 | Philip Head | Tubing and conductors or conduits |
| US6257332B1 (en) * | 1999-09-14 | 2001-07-10 | Halliburton Energy Services, Inc. | Well management system |
| CA2327987C (en) * | 1999-12-08 | 2008-02-19 | Robbins & Myers Energy Systems L.P. | Wellhead with improved esp cable pack-off and method |
| AU2001252234A1 (en) * | 2000-03-27 | 2001-10-08 | Rockwater Limited | Riser with retrievable internal services |
| US7396216B2 (en) * | 2002-04-23 | 2008-07-08 | Halliburton Energy Services, Inc. | Submersible pump assembly for removing a production inhibiting fluid from a well and method for use of same |
| NO323381B2 (en) * | 2005-01-31 | 2007-04-16 | Statoil Asa | Protective sleeve for surrounding an elongated object |
| CA2624401A1 (en) * | 2005-09-24 | 2007-03-29 | Philip Head | Coiled tubing and power cables |
| US20070151735A1 (en) * | 2005-12-21 | 2007-07-05 | Ravensbergen John E | Concentric coiled tubing annular fracturing string |
| CA2645948C (en) * | 2007-12-05 | 2013-07-16 | Baker Hughes Incorporated | High velocity string for well pump and method for producing well fluid |
| US9874077B2 (en) * | 2008-04-30 | 2018-01-23 | Altarock Energy Inc. | Method and cooling system for electric submersible pumps/motors for use in geothermal wells |
| US7905295B2 (en) * | 2008-09-26 | 2011-03-15 | Baker Hughes Incorporated | Electrocoil tubing cable anchor method |
| CA2707059C (en) * | 2010-06-22 | 2015-02-03 | Gerald V. Chalifoux | Method and apparatus for installing and removing an electric submersiblepump |
-
2015
- 2015-03-02 US US14/635,569 patent/US20160258231A1/en not_active Abandoned
-
2016
- 2016-02-26 WO PCT/US2016/019899 patent/WO2016140893A1/en active Application Filing
- 2016-02-26 GB GB1715591.2A patent/GB2552756A/en not_active Withdrawn
-
2017
- 2017-09-27 NO NO20171541A patent/NO20171541A1/en not_active Application Discontinuation
Also Published As
| Publication number | Publication date |
|---|---|
| WO2016140893A1 (en) | 2016-09-09 |
| GB201715591D0 (en) | 2017-11-08 |
| US20160258231A1 (en) | 2016-09-08 |
| GB2552756A (en) | 2018-02-07 |
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| FC2A | Withdrawal, rejection or dismissal of laid open patent application |