EP2754851B1 - Tuyau de forage amélioré - Google Patents

Tuyau de forage amélioré Download PDF

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Publication number
EP2754851B1
EP2754851B1 EP13151249.3A EP13151249A EP2754851B1 EP 2754851 B1 EP2754851 B1 EP 2754851B1 EP 13151249 A EP13151249 A EP 13151249A EP 2754851 B1 EP2754851 B1 EP 2754851B1
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EP
European Patent Office
Prior art keywords
main section
landing pipe
pipe
landing
tool joint
Prior art date
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Application number
EP13151249.3A
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German (de)
English (en)
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EP2754851A1 (fr
Inventor
Henry Yang
Scott Granger
Jonathan FRANCHI
Chris MCKLEMURRY
Kenneth GODEKE
Current Assignee (The listed assignees may be inaccurate. Google has not performed a legal analysis and makes no representation or warranty as to the accuracy of the list.)
Grant Prideco LP
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Grant Prideco LP
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Priority to EP13151249.3A priority Critical patent/EP2754851B1/fr
Priority to PL13151249T priority patent/PL2754851T3/pl
Priority to DK13151249.3T priority patent/DK2754851T3/da
Publication of EP2754851A1 publication Critical patent/EP2754851A1/fr
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Classifications

    • 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
    • E21B17/16—Drill collars

Definitions

  • the present disclosure relates to a tubular component used for drilling and operating hydrocarbon wells and landing heavy loads in a well or on or below the sea bed.
  • the term "drill string or landing string component” means any element with a substantially tubular shape intended to be connected to another element of the same type or not in order, when complete, to constitute either a string for drilling or performing operations within a hydrocarbon well or a string for landing heavy loads in a well or on or below the sea bed.
  • the invention is of particular application to other components used in a drill string or landing string such as drill pipes, heavy weight drill pipes, drill collars, and the parts which connect drill pipes, heavy weight drill pipes, and landing pipes known as tool joints.
  • gripping slips are used to grip an area on the drill string or landing string component below the component being removed from, or connected to, the drill string or landing string.
  • Gripping slips have inserts with teeth to clamp the drill string or landing string component below the drill string or landing string component being removed or reconnected, and hold up the unsupported weight of the string below the slips. Due to repeated gripping of certain drill string or landing string components by the gripping slips, the area of the drill string or landing string component where gripping takes place may be more subject to fatigue failure from repetitive loading and unloading, and notching from each application of the slips' teeth.
  • a drill string or landing string component with a suitably long part life is challenging, since the components in a drill string or landing string must be capable in many cases of withstanding high tensile and compressive loads, bending and rotation under stress, as well as frequent slips clamping which results in hoop stresses, notching, and potential crushing of the drill string or landing string component.
  • Wilson a thick wall rotary slip engaging elongated steel protector tube extending from the first tool joint to the main portion of the drill pipe, the protector tube having greater wall thickness than the main portion of the drill pipe, the protector tube being made of a Martensite steel having a small, close knit, grain size to reduce the penetration of the slip teeth that engage the protector tube when the joint is supported in the rotary table by slips
  • Wilson obtains a drill pipe with the protector tube that will run its full expected fatigue life without failing in notches and marks caused by slips in the rotary table.
  • HRC Rockwell Hardness
  • One advantage of an exemplary embodiment described herein lies in reducing landing pipe weight, which reduces loading of drill string and landing string components and other handling equipment and drilling rig components. Reducing pipe weight can increase part life and extend the potential reach of the landing string.
  • Another advantage of an exemplary embodiment described herein is an integral pipe design, where the pipe is designed with no welds. Identifying the location of a weld while running a landing pipe may increase the time required to run the pipe.
  • an integral design provides a larger vertical tolerance to apply the slips, such that it takes less time to set the landing pipe in the slips, leading to faster operations on a string.
  • an integral design yields a smoother bore with potentially less hydraulic turbulence, and less hang-up for tools.
  • a landing pipe comprises a first tool joint, a second tool joint, and a main section extending from the first tool joint to the second tool joint.
  • the first tool joint can be an upper tool joint and the second tool joint can be a lower tool joint, or vice versa.
  • the first tool joint outer diameter is greater than the largest main section outer diameter, and a first portion of the landing pipe main section has a greater tube wall thickness than a second portion of the landing pipe main section.
  • the tube wall thickness of the second portion of the landing pipe main section is reduced by boring the inner diameter.
  • the tube wall thickness of the second portion of the landing pipe main section is reduced by turning the outer diameter.
  • part of the first portion of the landing pipe main section can also have a reduced tube wall thickness directly adjacent to the first tool joint.
  • the length of the second portion of the main section is between 40-85 % of the overall landing pipe length, which provides sufficient length to set the slips. In a preferred embodiment, the length of the second portion of the main section is between 55-80 % of the overall landing pipe length.
  • the present invention comprises a landing pipe designed to minimize weight.
  • the present disclosure proposes an advantageous trade-off between wall thickness and overall weight, such that the landing pipe's resistance to crushing, tensile yielding, and fatigue is improved, yet the weight is manageable.
  • an exemplary landing pipe is composed of an upper tool joint (1), a main portion consisting of a first portion (2a), where slips are intended to engage the landing pipe, a second portion (2b), which has a lower tube wall thickness than the main portion to reduce weight, and a lower tool joint (3).
  • Tool joints may be of the pin and box type, and threaded, to allow mating of multiple landing pipes to form a drill string or landing string.
  • the material used for the landing pipe is a high strength low alloy (HSLA) material such as 4100 or 4300 series alloy steel.
  • HSLA high strength low alloy
  • An exemplary embodiment of the present disclosure uses an integral design, defined as a design without welds.
  • no weld is present on the landing pipe between the main section first portion and the main section second portion.
  • no welds are present between the tool joints and main section such that the landing pipe design is entirely integral.
  • Wilson nor Huntsinger discloses a design which is integral in part or as a whole.
  • An exemplary embodiment of the present disclosure may have both an integral design and different mechanical characteristics along its length.
  • the tube main section (2) requires a high yield strength to ensure a balance between pipe weight and resistance to tensile loads.
  • a preferred embodiment of the present disclosure may use a main section with a higher yield strength, and tool joints (1, 3) with a lower yield strength.
  • tool joints have a greater cross section than the main section, such that a higher force needs to be applied for the tool joint to yield, compared to the force required for the main section to yield.
  • Tool joint threads are prone to damage due to their irregular shape, and use of a lower yield strength may prevent cracks from initiating in the threads.
  • the yield strength range (determined by physical testing with 0.2 % offset) for the drill pipe's main section is between 930.8 MPa and 1241 MPa (135 ksi and 180 ksi).
  • a main section preferred yield strength range is between 1034 MPa and 1206 MPa (150 ksi and 175 ksi).
  • the yield strength range of the tool joints is between 827.4 MPa and 1103.1 MPa (120 ksi and 160 ksi).
  • a tool joint preferred yield strength range is between 930.8 MPa and 1034 MPa (135 ksi and 150 ksi).
  • desired mechanical characteristics are obtained by first heat treating the entire tube (1,2,3) to obtain the required yield strength for the tube main section (2), and then applying a localized heat treatment on the tool joints (1,3).
  • the localized heat treatment is applied using inductive coils, or any other method that ensures homogenous heat, both axially and throughout the thickness of the locally treated area.
  • This localized heat treatment uses the same temperature as the heat treatment for the entire tube, with a different treatment time (tempering time) based on the material and thickness used.
  • Tool joints treated with the localized heat treatment described above have lower yield strength and lower material hardness than the pipe's main section.
  • a transition area exists between the low yield strength portions (tool joints) and high yield strength portion (main section), which may be located on the tool joints, preferably 1" from the taper between the tool joint and the pipe main section.
  • the present disclosure does not use a protector tube. Indeed, the landing pipe's main section extends from one tool joint to the other tool joint. According to the present disclosure, the tube wall thickness is not increased. Instead, the present disclosure reduces the landing pipe weight by removing material from the main section's second portion.
  • the main section should have a higher hardness than the protector tube (notching being less of an issue outside of the protector tube).
  • the present invention does not use a protector tube. Instead, the present invention can include a single main section between the tool joints. In a preferred embodiment, there is no section between the tool joints with a hardness lower than that of the main section, and there is no section characteristic of a protector tube.
  • the present disclosure utilizes a standard API drill pipe nominal outer diameter (OD) of 168,275 mm (6 5/8") for the main section, the main section first portion (2a) having a constant inner diameter (ID), and the main section second portion (2b) having an ID greater than that of the main section first portion.
  • Nominal values can be assigned certain tolerances to accommodate customers and industry specifications.
  • One example of an acceptable manufacturing tolerance is 1.5748 mm (62/1000").
  • Field tolerances may be up to 90 % of the remaining wall thickness.
  • the main section second portion (2b) is bored out, increasing the inner diameter. Referring to Fig.
  • part of the first portion of the main section (2c) can also be bored out to an ID greater than the main section first portion to reduce weight, in a region beginning at a first tool joint and finishing at most 914.4 mm (36") below the elevator shoulder of the first tool joint, defined as the junction between the main portion and the first tool joint.
  • One advantage of this embodiment is improved landing pipe handling, which results from using a constant drill pipe API OD along the entire main section length.
  • the present disclosure utilizes for the landing pipe main section first portion (2a) a non-API drill pipe OD of 175.41875 mm (6 29/32") nominal, which is compatible with commonly used landing pipe handling equipment on rigs. While the landing pipe in this embodiment displays changes in outer diameter, new generation rigs prevalently can and often use an API compatible elevator and slip system with which the present invention is compatible with certain adjustments.
  • the main section second portion (2b) has a standard API drill pipe nominal OD (168,275 mm (6 5/8")) to reduce weight, rather than a nominal 175.41875 mm (6 29/32") OD for the full length of the main section.
  • part of the first portion of the landing pipe main section (2c) can be turned down to an OD lower than the OD of the first portion (2b) of the landing pipe main section to reduce weight, in a region beginning at an upper tool joint elevator shoulder and finishing at most 914.4 mm (36") below the elevator shoulder of the upper tool joint.
  • One advantage of this embodiment is the increased landing pipe slips area diameter and the smooth ID bore throughout the length of the landing pipe.
  • a smooth bore such as the one present in this preferred embodiment, minimizes fluid pressure losses compared to non-integral designs with offsets and irregularities.
  • the reduction in the OD of the main section first portion directly adjacent to the upper tool joint elevator shoulder can either increase or maintain the elevator shoulder surface area, allowing a modified elevator bore or elevator bushing bore to have an increased or maintained loading capacity with a decreased tool joint OD.
  • the wall thickness of the main section second portion is reduced such that the landing pipe weight is reduced by at least 5 % compared to a landing pipe with the wall thickness of the main section first portion equal to the main wall thickness of the main section second portion.
  • the length of the second portion (2b) of the main section is between 40-85 % of the overall landing pipe length, which provides sufficient length to set the slips. In a preferred embodiment, the length of the second portion of the main section is between 55-80 % of the overall pipe length. In another preferred embodiment, the length of the second portion of the main section is between 55 % and 65 % of the overall pipe length.

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  • Engineering & Computer Science (AREA)
  • Life Sciences & Earth Sciences (AREA)
  • Geology (AREA)
  • Mining & Mineral Resources (AREA)
  • Mechanical Engineering (AREA)
  • Physics & Mathematics (AREA)
  • Environmental & Geological Engineering (AREA)
  • Fluid Mechanics (AREA)
  • General Life Sciences & Earth Sciences (AREA)
  • Geochemistry & Mineralogy (AREA)
  • Earth Drilling (AREA)

Claims (18)

  1. Tuyau de forage comprenant :
    un premier joint d'outil (1) avec un diamètre extérieur de premier joint d'outil ;
    un second joint d'outil (3) avec un diamètre extérieur de second joint d'outil ;
    une section principale (2) s'étendant du premier joint d'outil au second joint d'outil, ladite section principale présentant une première partie de section principale (2a) et une seconde partie de section principale (2b), dans lequel
    la première partie de section principale présente un diamètre extérieur de première partie, un diamètre intérieur de première partie, et une épaisseur de paroi de première partie qui représente la moitié d'une différence entre le diamètre extérieur de la première partie et le diamètre intérieur de première partie,
    la seconde partie de section principale présente un diamètre extérieur de seconde partie, un diamètre intérieur de seconde partie et une épaisseur de paroi de seconde partie qui représente la moitié d'une différence entre le diamètre extérieur de la seconde partie et le diamètre intérieur de la seconde partie ;
    le diamètre extérieur du premier joint d'outil est supérieur au diamètre extérieur de première partie et au diamètre extérieur de seconde partie ; et l'épaisseur de paroi de première partie (2a) est supérieure à l'épaisseur de paroi de seconde partie (2b),
    la seconde partie de section principale (2b) présente une plage de longueur comprise entre 40 % et 85 % d'une longueur totale du tuyau de forage et le diamètre extérieur de la première partie de la section principale est égal au diamètre extérieur de la seconde partie de la section principale, et le diamètre intérieur de la seconde partie de la section principale est supérieur au diamètre intérieur de la première partie de section principale et caractérisé en ce que la première partie de la section principale est d'un seul tenant avec la seconde partie de la section principale, sans soudure entre la section principale et les deux joints d'outil.
  2. Tuyau de forage selon la revendication 1, dans lequel le premier joint d'outil, la section principale et le second joint d'outil sont d'un seul tenant l'un avec l'autre, sans soudure entre eux.
  3. Tuyau de forage selon la revendication 1, dans lequel le diamètre extérieur de la première partie et le diamètre extérieur de la seconde partie sont de 168,275 mm (6 5/8") nominaux.
  4. Tuyau de forage selon la revendication 1, dans lequel une partie de la première partie de la section principale commençant au premier joint d'outil et se terminant au plus à 914,4 mm (36") sous un épaulement d'élévateur du premier joint d'outil présente un diamètre interne qui est supérieur au diamètre intérieur de la première partie de la section principale.
  5. Tuyau de forage selon la revendication 1, dans lequel une plage de capacité de charge de traction pour le tuyau de forage est comprise entre 700 000 kg (1,5 million de livres) et 2 millions de kg (4,5 millions de livres).
  6. Tuyau de forage selon la revendication 1, dans lequel un matériau du tuyau de forage est un acier faiblement allié à résistance élevée.
  7. Tuyau de forage selon la revendication 6, dans lequel le matériau du tuyau de forage présente une plage de limite d'élasticité comprise entre 930,8 et 1241 MPa (135 ksi et 180 ksi) sur la section principale de tuyau.
  8. Tuyau de forage selon la revendication 7, dans lequel le matériau du tuyau de forage présente une plage de limite d'élasticité comprise entre 1034 et 1206 MPa (150 ksi et 175 ksi) sur la section principale de tuyau.
  9. Tuyau de forage selon la revendication 6, dans lequel le matériau du tuyau de forage présente une plage de limite d'élasticité comprise entre 827,4 et 1103,1 MPa (120 ksi et 160 ksi) sur les joints d'outil.
  10. Tuyau de forage selon la revendication 9, dans lequel le matériau du tuyau de forage présente une plage de limite d'élasticité comprise entre 930,8 et 1034 MPa (135 ksi et 150 ksi) sur les joints d'outil.
  11. Tuyau de forage selon la revendication 1, dans lequel la seconde partie de la section principale présente une plage de longueur comprise entre 55 % et 80 % de la longueur totale du tuyau de forage.
  12. Tuyau de forage selon la revendication 1, dans lequel la limite d'élasticité des joints d'outil est inférieure à la limite d'élasticité de la section principale du tuyau de forage.
  13. Tuyau de forage selon la revendication 1, dans lequel l'épaisseur de paroi de la seconde partie de la section principale est réduite de sorte qu'une réduction de poids pour le tuyau de forage soit d'au moins 5 % par rapport à un tuyau de forage dont l'épaisseur de paroi de la première section de partie principale est égale à l'épaisseur de paroi de la seconde section de partie principale.
  14. Tuyau de forage selon la revendication 1, dans lequel la seconde partie de la section principale est directement adjacente au second joint d'outil.
  15. Tuyau de forage selon la revendication 1, comprenant une partie filetée sur au moins un joint d'outil, dans lequel une telle partie filetée présente une limite d'élasticité inférieure et une dureté réduite par rapport à la section principale.
  16. Tuyau de forage selon la revendication 15, dans lequel une limite d'élasticité inférieure et une dureté réduite par rapport à la section principale résultent d'un traitement thermique localisé de la partie filetée.
  17. Tuyau de forage selon la revendication 1, comprenant une zone de transition de limite d'élasticité entre une partie d'un joint d'outil et la section principale du tuyau de forage, ladite zone de transition de limite d'élasticité étant d'au moins 25,4 mm (1") depuis un rétrécissement entre la partie d'un joint d'outil et la section principale du tuyau de forage.
  18. Tuyau de forage selon la revendication 17, dans lequel la zone de transition de limite d'élasticité résulte d'un traitement thermique localisé de la partie d'un joint d'outil.
EP13151249.3A 2013-01-15 2013-01-15 Tuyau de forage amélioré Active EP2754851B1 (fr)

Priority Applications (3)

Application Number Priority Date Filing Date Title
EP13151249.3A EP2754851B1 (fr) 2013-01-15 2013-01-15 Tuyau de forage amélioré
PL13151249T PL2754851T3 (pl) 2013-01-15 2013-01-15 Ulepszona rura wiertnicza
DK13151249.3T DK2754851T3 (da) 2013-01-15 2013-01-15 Forbedret borerør

Applications Claiming Priority (1)

Application Number Priority Date Filing Date Title
EP13151249.3A EP2754851B1 (fr) 2013-01-15 2013-01-15 Tuyau de forage amélioré

Publications (2)

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EP2754851A1 EP2754851A1 (fr) 2014-07-16
EP2754851B1 true EP2754851B1 (fr) 2019-03-06

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EP (1) EP2754851B1 (fr)
DK (1) DK2754851T3 (fr)
PL (1) PL2754851T3 (fr)

Family Cites Families (4)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US3080179A (en) * 1959-10-06 1963-03-05 Huntsinger Associates Slip engaging portion of drill string formed of increased wall thickness and reduced hardness
US4771811A (en) * 1984-04-20 1988-09-20 Lor, Inc. Heavy wall drill pipe and method of manufacture of heavy wall drill pipe
US4987961A (en) * 1990-01-04 1991-01-29 Mcneely Jr Branch M Drill stem arrangement and method
US5562312A (en) * 1994-07-05 1996-10-08 Grant Tfw, Inc. Discountinuous plane weld apparatus and method for enhancing fatigue and load properties of subterranean well drill pipe immediate the area of securement of pipe sections

Non-Patent Citations (1)

* Cited by examiner, † Cited by third party
Title
None *

Also Published As

Publication number Publication date
DK2754851T3 (da) 2019-06-11
PL2754851T3 (pl) 2019-09-30
EP2754851A1 (fr) 2014-07-16

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