USRE34017E - Increased tensile strength variable diameter protective joint - Google Patents
Increased tensile strength variable diameter protective joint Download PDFInfo
- Publication number
- USRE34017E USRE34017E US07/248,629 US24862988A USRE34017E US RE34017 E USRE34017 E US RE34017E US 24862988 A US24862988 A US 24862988A US RE34017 E USRE34017 E US RE34017E
- Authority
- US
- United States
- Prior art keywords
- protective
- ring
- tubular
- rings
- face
- Prior art date
- Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
- Expired - Lifetime
Links
- 230000001681 protective effect Effects 0.000 title claims abstract description 164
- 230000007704 transition Effects 0.000 claims abstract description 110
- 238000007363 ring formation reaction Methods 0.000 claims abstract description 45
- 230000008878 coupling Effects 0.000 claims description 67
- 238000010168 coupling process Methods 0.000 claims description 67
- 238000005859 coupling reaction Methods 0.000 claims description 67
- 238000009826 distribution Methods 0.000 claims description 27
- 238000005452 bending Methods 0.000 claims description 13
- 125000006850 spacer group Chemical group 0.000 claims description 7
- 238000004519 manufacturing process Methods 0.000 abstract description 23
- 239000000463 material Substances 0.000 description 7
- 239000007789 gas Substances 0.000 description 6
- 239000000919 ceramic Substances 0.000 description 5
- 239000003129 oil well Substances 0.000 description 5
- 230000008901 benefit Effects 0.000 description 4
- UONOETXJSWQNOL-UHFFFAOYSA-N tungsten carbide Chemical compound [W+]#[C-] UONOETXJSWQNOL-UHFFFAOYSA-N 0.000 description 4
- 230000006835 compression Effects 0.000 description 3
- 238000007906 compression Methods 0.000 description 3
- 238000005520 cutting process Methods 0.000 description 3
- 239000012530 fluid Substances 0.000 description 3
- 238000003466 welding Methods 0.000 description 3
- 230000008859 change Effects 0.000 description 2
- 238000005336 cracking Methods 0.000 description 2
- 230000003116 impacting effect Effects 0.000 description 2
- 229910052751 metal Inorganic materials 0.000 description 2
- 239000002184 metal Substances 0.000 description 2
- 238000012986 modification Methods 0.000 description 2
- 230000004048 modification Effects 0.000 description 2
- 239000002245 particle Substances 0.000 description 2
- 239000012858 resilient material Substances 0.000 description 2
- 239000004576 sand Substances 0.000 description 2
- 239000007787 solid Substances 0.000 description 2
- 229910000831 Steel Inorganic materials 0.000 description 1
- 239000003082 abrasive agent Substances 0.000 description 1
- 239000006096 absorbing agent Substances 0.000 description 1
- 230000009471 action Effects 0.000 description 1
- 230000000712 assembly Effects 0.000 description 1
- 238000000429 assembly Methods 0.000 description 1
- 230000004323 axial length Effects 0.000 description 1
- 230000015572 biosynthetic process Effects 0.000 description 1
- 208000002352 blister Diseases 0.000 description 1
- 229910010293 ceramic material Inorganic materials 0.000 description 1
- 239000011248 coating agent Substances 0.000 description 1
- 238000000576 coating method Methods 0.000 description 1
- 230000000694 effects Effects 0.000 description 1
- 230000003628 erosive effect Effects 0.000 description 1
- 238000009434 installation Methods 0.000 description 1
- 239000007788 liquid Substances 0.000 description 1
- 238000005259 measurement Methods 0.000 description 1
- 238000000034 method Methods 0.000 description 1
- 239000003921 oil Substances 0.000 description 1
- 230000001012 protector Effects 0.000 description 1
- 230000035939 shock Effects 0.000 description 1
- 238000004904 shortening Methods 0.000 description 1
- 239000010959 steel Substances 0.000 description 1
Images
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
- E21B17/10—Wear protectors; Centralising devices, e.g. stabilisers
- E21B17/1085—Wear protectors; Blast joints; Hard facing
-
- 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
- F16L57/00—Protection of pipes or objects of similar shape against external or internal damage or wear
Definitions
- the invention pertains to protective devices for tubular goods and more particularly to increased tensile strength variable diameter protective joints for use as so called blast joints with oil well production tubing.
- a number of patents disclose a variety of blast joints for tubulars.
- Duesterberg U.S. Pat. No. 2,925,097, discloses a covered tubular member for positioning in a well flow pipe.
- a tubular member is provided with a covering which is said to protect the tubular member from the cutting action of well fluids.
- the covering includes a coating of a resilient material which may be arranged on the outer surface of the tubular member in strip form.
- a sleeve formed of hard, brittle material covers the surface of the tubular member between two collars. The collars are adjacent to each end of the tubular member.
- the sleeve may be formed by a plurality of tubular members which are said to be in end to end interfitting or overlapping relation. Each of the plurality of tubular members forming the sleeve may be provided with recessed portions for interfitting and overlap.
- a second layer of resilient material is provided on substantially all of the outer surface of the sleeve to act as a shock absorber to protect the sleeve from breakage or damage as the tubular member and connected pipe sections are lowered into position in the well bore.
- an outer shell of metal may be provided which extends between the collars and is secured to each collar by welding.
- the blast joint employing a ceramic material said to resist the eroding action of a fluid flowing against the joint.
- the blast joint includes a ceramic sleeve made up of a plurality of tubular ceramic members that are slipped on a tubing joint in end to end relationship.
- the ceramic members are held in position by annular collars of an impact resistant, non-brittle material, such as steel. They are provided with a plurality of set screws which engage the tubing joint and hold the collars and the ceramic members between them against longitudinal movement on the joint.
- the annular collars are spaced from the ends of the tubing joint.
- a protector made up of an annular ring is located in a groove on the exterior of the blast joint and encircles it to prevent the blast joint from hanging upon obstructions in the well bore.
- Means are also provided as a cushion between ceramic members and means for holding the members spaced from the tubing string.
- Prior devices suffer from one or more of several difficulties or limitations including difficulties or limitations in handling, shipping, manufacturing, assembly, overall effectiveness, longevity, and reusability. Many of these problems are addressed by one or more of the inventions previously assigned to the same assignee as this invention. However, prior devices still suffer from a limitation in not being able to directly and as effectively protect both the tubular and an increased diameter portion of the tubular such as collars used with external non-upset tubing and upset tubing. Further, prior devices have been unable to provide as effective a protective device covering a plurality of tubulars, such as oil well tubing, without impairing the tensile strength of the tubing string. These and other problems encountered with prior devices .[.as.]. .Iadd.are .Iaddend.alleviated if not substantially eliminated by the present invention.
- a protective joint for tubulars such as oil well production tubing, having a body portion with a first diameter and at least one coupling portion having an increased diameter portion. At least a part of both the first and increased diameter portions are included within a zone to be protected by the protective joint.
- the protective joint includes a plurality of first and second generally cylindrical annular protective rings such as carbide rings.
- the first protective rings are coaxially located along the body portion of the tubular.
- the second protective rings are coaxially located along the increased diameter portion of the upset.
- the first and second protective rings have flat and parallel faces and are sized and configured to accommodate bending movements along the longitudinal axis of the tubular.
- first and second protective rings may have flattened parallel faces, sufficient inside diameters and be engagable with like protective rings along a plane intersecting and normal to the inside longitudinal axis of the tubular to accommodate bending movements along the longitudinal axis of the tubular.
- a transition ring formation is also provided.
- the transition ring formation has first and second flat and parallel faces .Iadd.engageable with the first and second protective rings, respectively.Iaddend..
- the transition ring formation also has an inside diameter and an outside diameter at its first face approximately equal to the inside and outside diameter, respectively, of the first protective rings.
- the inside diameter and outside diameter of the transition ring formation at its second face is approximately equal to the inside and outside diameter, respectively, of the second protective rings.
- the exterior surface of the transition ring formation is a generally continuous one extending from the first face to the second face of the transition ring formation.
- the interior surface of the transition ring formation is configured to provide a space along the connection between the coupling portion and the body portion of the tubular sufficient to accommodate longitudinal movement of the protective joint with respect to the tubular.
- biasing means coaxially located along some portion of the tubular for engagement with at least one of the protective rings.
- the biasing means in conjunction with retainers are configured to bias the first and second protective rings and the transition ring formation and so form a protective shield along the entire zone to be protected.
- the biasing means may include a plurality of wave springs and spacers.
- the transition ring formation may take on a number of configurations.
- the interior surface of the transition ring formation may be a generally continuous surface.
- the interior surface of the transition ring formation may be a substantially discontinuous surface.
- the transition ring formation may include one or more integrally mated units or rings.
- the transition ring formation is preferably made up of a plurality of rings of sufficient length along the axis of the tubular to accommodate bending movements in the tubular while remaining substantially sealingly engaged.
- the plurality of engagable rings preferably have flat and parallel faces normal to the longitudinal axis of the tubular.
- the transition ring formation is made up of a number of rings, it may include a transition ring, a supporting ring, such as a weight distributing or impact distributing ring, and a compensating ring.
- Each of these rings have first and second flat and parallel faces and are coaxially disposed with respect to the interior of the longitudinal axis of the tubular.
- the transition ring is engagable on its first face with at least one of the first protective rings and has an inside diameter approximately equal to the inside diameter of the first protective rings and an outside diameter varying from the outside diameter of the first protective rings at its first face to an expanded outside diameter at its second face.
- the supporting ring has an inside diameter approximately equal to the inside diameter of the transition ring and an outside diameter approximately equal to the expanded outside diameter of the transition ring at the second face of the transition ring.
- the first face of the supporting ring is engagable with the second face of the transition ring.
- the compensating ring has an outside diameter approximately equal to the outside diameter of the supporting ring and an expanded inside diameter. The expanded diameter of the compensating ring is sufficient to accommodate the increased diameter of the coupling.
- the interior surface of the compensating ring is configured in relation to the exterior surface of the coupling and the body portion to provide sufficient spacing to accommodate longitudinal movement of the protective device with respect to the tubular.
- the length of the compensating ring may vary from the length of the second protective rings.
- the protective rings and the rings making up the transition ring formation are preferably made of carbide or a material having characteristics similar to carbide.
- the rings making up the transition ring formation may take on a number of forms within the framework of the present disclosure.
- the transition ring may be a cone shaped ring having an expanding inside diameter, as for example where the tubular is an integral joint pipe.
- some of the rings may be integrally mated to each other.
- FIG. 1 is a schematic view of one embodiment of the present invention shown in an environment in which it may be used;
- FIG. 2 is a cutaway view of a protective joint shown in conjunction with a non-upset threaded and coupled joint;
- FIG. 3 is a cutaway view of a protective joint in conjunction with an external upset coupling
- FIG. 4 is a cutaway view of a protective joint in conjunction with an integral joint
- FIG. 5 is a partial cutaway view of a protective joint shown generally in FIG. 1 in conjunction with a non-upset threaded and coupled joint;
- FIG. 6 is a partial schematic view of the protective joint shown in FIG. 5;
- FIG. 7 is a partially exploded view of portions of the protective device shown generally in FIG. 5.
- FIG. 1 shows a schematic view of one embodiment of the present invention in a well 10 having perforations 11 through which gas or oil entrained particles are escaping and impacting portions of the tubular string made up of tubing joints 12 and couplings 14.
- the couplings 14 have increased diameters and are otherwise constructed to provide sufficient tensile strength to support the production string. Although couplings, such as flush joints, having no increase in diameter are sometimes employed, this can be disadvantageous since such couplings generally have only about 50% of the strength of couplings having increased diameters.
- the perforations or openings 11 can be located by either the tubular joint 12 or the coupling 14 or both, thus placing both within a zone to be protected on the tubular string.
- a protective joint for a tubular assembly having a body portion, such as a tubing joint 12, and at least one coupling portion, such as coupling 14, with an increased outside diameter.
- the protective joint includes a plurality of first generally cylindrical annular protective rings, such as tubing body rings 22, and a plurality of second generally cylindrical annular protective rings, such as coupling body rings 32.
- the tubing body rings 22 are coaxially locatable along the tubing joint 12 while the coupling body rings 32 are coaxially locatable along the coupling 14.
- the tubing body rings 22 and the coupling body rings 32 have flat and parallel faces normal to the longitudinal axis of the tubular and are sealingly engagable with like rings.
- transition ring formation 40 has two flat and parallel faces which are sealingly engagable with tubing body rings 22 and coupling body rings 32, respectively.
- the transition ring formation is configured to provide a .Iadd.longitudinal .Iaddend.space, such as space 70, along the connection between the coupling portion, such as coupling 14, and the body portion of the tubular, such as tubing joint 12.
- the .Iadd.longitudinal .Iaddend.space .Iadd.70 between the increased diameter coupling portion 14 and the next longitudinally adjacent portion 43 of the protective joint .Iaddend. is sufficient to accommodate relative longitudinal movement of the tubular assembly with respect to the protective device.
- Biasing means such as wave springs 52 and spacers 54 are also provided and are engagable at one end with at least one of the protective rings such as tubing body rings 22. At the other end the biasing means is engagable with a retainer such as collar 62. A second retainer, such as another collar 64, is also engagable with protective rings, such as tubing body rings 22. The biasing means is engagable at one end with a retainer and at the other end with at least one of the protective rings to thereby bias the tubing body rings 22, the coupling body rings 32 and the transition ring formation 40 to thereby form a protective shield along a zone of the tubular encompassing varying outside diameters.
- the transition ring formation may take on a variety of configurations depending on the application and the type of tubular assembly or connection employed.
- the transition ring formation may preferably include a plurality of rings including a transition ring, such as ring 42, a weight distribution or impact distribution ring such as ring 44 and a compensating ring such as ring 46.
- the various rings may be sealingly engaged with each other, yet respond to translational forces as might be caused by bending or flexing of a tubing string.
- the weight distribution or impact distribution ring 44 is also coaxially located along the tubing joint 12 prior to its juncture with the coupling 14.
- the weight distribution ring 46 has an outside diameter equal to the increased outside diameter of the transition ring 42 at its second face 50 and an inside diameter equal to that of the transition ring 42. It can thus be seen that the transition ring 42 and the weight distribution ring 46 provide a zone of uniform interior cross section and diameter with an increase in outside diameter along the longitudinal axis of the tubular.
- the walls 59 of the weight distribution or impact distribution ring 44 should provide sufficient support to minimize any damage to the transition ring 42 when the tubing joint and coupling are moved in and out of confined areas.
- the compensating ring such as ring 46 is only partially coaxially located along the coupling 14.
- the compensating ring 46 has an outside diameter equal to the outside diameter of the coupling body rings 32 and the weight distribution ring 44, it has an inside diameter equal to the inside diameter of the coupling body rings 32 and larger than the inside diameter of the weight distribution ring 44.
- This change in inside diameter of the transition ring formation between the inside diameter of the weight distribution ring 44 and the inside diameter of the compensating ring 46 coupled with the overlap of the compensating ring 46 beyond the end of the juncture of the coupling 14 and the tubing joint 12 provides a space 70.
- the space 70 formed by the inside wall of the compensating ring 46, a portion of the second face 58 of the compensating ring 46, a portion of the outer surface of the tubing joint 12 and the coupling 14, may have a length along the longitudinal axis of the tubular assembly of at least one-fourth of an inch but preferably of one-half of an inch.
- the compensating ring such as ring 46
- the compensating ring may simply consist of another coupling ring 32.
- space 70 it is believed important to provide a sufficient space, such as space 70, to accommodate the expected longitudinal movement of the tubular with respect to the protective joint.
- FIG. 3 there is shown a variation of the protective joint for use with an API external upset coupling.
- the interior surface of a transition ring 82 increases in diameter from its first face to its second face to accommodate the area of expanded outside diameter caused by the integral upset 16 on the tool joint 18.
- a weight distribution ring 84 and a compensating ring 86 are similar in configuration to their counterparts in the embodiment shown in FIGS. 5 and 6.
- a similar space, space 86, is also provided to accommodate relative longitudinal movement.
- the transition ring formation may comprise one integral ring or a plurality of integrally mated cone shaped rings.
- the transition ring formation may include a number of cone shaped rings 92 having areas of expanding inside or outside diameter or both to accommodate an API integral joint.
- a space, space 96, is provided to accommodate relative longitudinal movement.
- the rings should preferably be no more than about one to one and one-half inches in length with respect to the longitudinal axis of the tubular assembly.
- the transition rings 82 or 92 are approximately more than one inch in length then a plurality of rings should be employed.
- a series of cone shaped rings 92 such as where the length of the upset portion 94 is greater than an inch to two inches.
- the protective rings employed are preferably made of carbide or a material having characteristics similar to carbide. More particularly, the rings making up the protective device are preferably made up of cemented tungsten carbide produced in the form of rings which may be placed shoulder-to-shoulder axially in line along the length of the tubular assembly to be protected.
- the cemented tungsten carbide has provided resistance of great strength and hardness and non-corrodible character which is capable of enduring the impact or blast of liquids or gases bearing entrained sand or other abrasive materials from underground high pressure sources.
- a protective joint in accordance with the disclosure provides effective protection for the tubing joint and should also provide effective protection along zones of increased diameter, particularly where the axial length of any of the rings is limited.
- the first and second protective rings may thus consist of cemented tungsten carbide produced in the form of short cylindrical rings with flat and parallel faces which may be held in shoulder-to-shoulder contact with each other.
- the transition formation may likewise be made of cemented tungsten carbide.
- the protective rings thus provide effective protection while being able to accommodate bending movements along the longitudinal axis of the tubular.
- the retainers may take on a number of configurations.
- the retainers may comprise collars such as collars 62 and 64.
- the collars 62 and 64 are of an internal diameter of a size sufficient to fit snugly on the external cylindrical surface of the tubing joint 12.
- a series of Allen head set screws 66 are seated in threaded holes in the collars 62 and 64 and are designed to grip the tubing joint 12 when the screws are tightened or release the tubing joint 12 when the screws are loosened.
- the collars 62 and 64 are believed to be preferably of an internal diameter less than that of the coupling 14, it may be feasible in some instances to employ collars on a segment of the coupling 14.
- the tubular body rings were sometimes chipped in compression on the concave side because the supporting production tubing is in some degree elastic and with the relatively heavy inelastic rings being held tightly endwise between the end clamping rings and being inflexible, they were subjected to high localized compressive stresses being forced together on the concave side of the bend and tending to be separated from each other on the convex side. While the production tube could stretch and the rings could separate on the convex side to some degree, there is not adequate freedom for shortening of the concave side because the rings occupied the available space and are literally incompressible.
- the biasing means may also serve to facilitate the handling of stress downhole.
- tubular assembly includes a non-upset threaded and coupled joint for 23/8" tubing the following dimensions are generally believed to be preferable:
- the protective joint may be used on a fairly wide range of tubing.
- any two of the rings may be integrally mated to each other either as a forged single piece or by welding.
- any two of the rings may be integrally mated to each other either as a forged single piece or by welding.
- the transition ring and the supporting ring may be formed into one integral piece.
Landscapes
- Engineering & Computer Science (AREA)
- Mechanical Engineering (AREA)
- Life Sciences & Earth Sciences (AREA)
- Geology (AREA)
- Mining & Mineral Resources (AREA)
- General Engineering & Computer Science (AREA)
- Physics & Mathematics (AREA)
- Environmental & Geological Engineering (AREA)
- Fluid Mechanics (AREA)
- General Life Sciences & Earth Sciences (AREA)
- Geochemistry & Mineralogy (AREA)
- Earth Drilling (AREA)
Abstract
Description
______________________________________ Inventor Patent No. Entitled ______________________________________ Bergstrom, 4,349,050 Blast Joint for Subterranean Wells Blast Joint Bergstrom 4,141,386 Blast Joint Bergstrom 4,028,796 Method of Making the Blast Joint Bergstrom 4,211,440 Compensated Blast Joint for Oil Well Production Tubing ______________________________________
______________________________________ Measurement in Inches ______________________________________ Inside diameter of the tubing joint 12 .sup. 1.995.sup.1 Outside diameter of the tubing joint 12 2.375 Inside diameter of the coupling 14 1.995 Outside diameter of the coupling 14 2.875 Inside diameter of the tubing body rings 22 2.420 Thickness of the tubing body rings 22 0.250 Inside diameter of the coupling body rings 32 2.930 Thickness of the coupling body rings 32 0.250 Length of collars 62 and 64 2.750 Inside diameter of the transition ring 42 2.420 Minimum thickness of the transition ring 42 0.250 at its first face 48 Maximum thickness of the transition ring 42 0.540 at its second face 50 Maximum diameter of the transition ring 42 3.500 Outside diameter of the weight distribution 3.500 or impact distribution ring 44 Inside diameter of the impact distribution 2.420 ring 44 Inside diameter of compensating ring 46 2.930 Wall thickness of compensating ring 46 0.250 Length of coupling body rings 32 1.000 Length of tubing body rings 32 1.000 Length of each of two compensating rings 46 1.250 Length of space 70 from the second face 54 0.500 of weight distribution ring 44 to the juncture of tubing joint 12 and coupling 14 Difference between outside surface of 0.0275 coupling 14 and inside surface of coupling body rings 32 Length of coupling 14 6.5 Number of coupling body rings 32 5 Inside diameter of collar 62 and 64 2.420 Number of wave springs 52 20.sup.2 Number of spacers 54 5.sup.3 ______________________________________ .sup.1 Normal drift. .sup.2 Can vary with length of blast joint and temperature. .sup.3 There are preferably four wave springs for each spacer.
Claims (23)
Priority Applications (1)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
US07/248,629 USRE34017E (en) | 1985-05-10 | 1988-09-23 | Increased tensile strength variable diameter protective joint |
Applications Claiming Priority (2)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
US06/732,703 US4613165A (en) | 1985-05-10 | 1985-05-10 | Increased tensile strength variable diameter protective joint |
US07/248,629 USRE34017E (en) | 1985-05-10 | 1988-09-23 | Increased tensile strength variable diameter protective joint |
Related Parent Applications (1)
Application Number | Title | Priority Date | Filing Date |
---|---|---|---|
US06/732,703 Reissue US4613165A (en) | 1985-05-10 | 1985-05-10 | Increased tensile strength variable diameter protective joint |
Publications (1)
Publication Number | Publication Date |
---|---|
USRE34017E true USRE34017E (en) | 1992-08-04 |
Family
ID=26939470
Family Applications (1)
Application Number | Title | Priority Date | Filing Date |
---|---|---|---|
US07/248,629 Expired - Lifetime USRE34017E (en) | 1985-05-10 | 1988-09-23 | Increased tensile strength variable diameter protective joint |
Country Status (1)
Country | Link |
---|---|
US (1) | USRE34017E (en) |
Cited By (2)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US20060006640A1 (en) * | 2004-07-12 | 2006-01-12 | Benoit Machine L.L.C. | Pipe coupling device |
US20080086866A1 (en) * | 2006-10-12 | 2008-04-17 | Husky Injection Molding Systems Ltd. | Molding system including body overlapping and sealing conduits, amongst other things |
Citations (8)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US320683A (en) * | 1885-06-23 | Half to j | ||
US1880269A (en) * | 1928-07-06 | 1932-10-04 | Metropolitan Eng Co | Hollow fitting |
US2925097A (en) * | 1958-09-08 | 1960-02-16 | Gerhard J Duesterberg | Covered tubular member for positioning in well flow pipe |
US3382930A (en) * | 1966-03-09 | 1968-05-14 | Keystone Valve Corp | Blast joint |
US4028746A (en) * | 1975-07-28 | 1977-06-14 | Huck Gerald N | Portable toilet |
US4141386A (en) * | 1975-07-31 | 1979-02-27 | Bergstrom Arthur E | Blast joint |
US4211440A (en) * | 1975-07-31 | 1980-07-08 | Bergstrom Arthur E | Compensated blast joint for oil well production tubing |
US4349050A (en) * | 1980-09-23 | 1982-09-14 | Carbide Blast Joints, Inc. | Blast joint for subterranean wells |
-
1988
- 1988-09-23 US US07/248,629 patent/USRE34017E/en not_active Expired - Lifetime
Patent Citations (8)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US320683A (en) * | 1885-06-23 | Half to j | ||
US1880269A (en) * | 1928-07-06 | 1932-10-04 | Metropolitan Eng Co | Hollow fitting |
US2925097A (en) * | 1958-09-08 | 1960-02-16 | Gerhard J Duesterberg | Covered tubular member for positioning in well flow pipe |
US3382930A (en) * | 1966-03-09 | 1968-05-14 | Keystone Valve Corp | Blast joint |
US4028746A (en) * | 1975-07-28 | 1977-06-14 | Huck Gerald N | Portable toilet |
US4141386A (en) * | 1975-07-31 | 1979-02-27 | Bergstrom Arthur E | Blast joint |
US4211440A (en) * | 1975-07-31 | 1980-07-08 | Bergstrom Arthur E | Compensated blast joint for oil well production tubing |
US4349050A (en) * | 1980-09-23 | 1982-09-14 | Carbide Blast Joints, Inc. | Blast joint for subterranean wells |
Cited By (3)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US20060006640A1 (en) * | 2004-07-12 | 2006-01-12 | Benoit Machine L.L.C. | Pipe coupling device |
US20080086866A1 (en) * | 2006-10-12 | 2008-04-17 | Husky Injection Molding Systems Ltd. | Molding system including body overlapping and sealing conduits, amongst other things |
US7575428B2 (en) * | 2006-10-12 | 2009-08-18 | Husky Injection Molding Systems Ltd. | Molding system including body overlapping and sealing conduits, amongst other things |
Similar Documents
Publication | Publication Date | Title |
---|---|---|
US4613165A (en) | Increased tensile strength variable diameter protective joint | |
US4067596A (en) | Dual flow passage drill stem | |
EP0890706B1 (en) | Slip retaining system for downhole tools | |
US4141386A (en) | Blast joint | |
US5540279A (en) | Downhole tool apparatus with non-metallic packer element retaining shoes | |
US3993368A (en) | Tool joint wear protectors | |
US6283205B1 (en) | Polymeric centralizer | |
US3998479A (en) | Dual conduit drill stem member and connection | |
US6585043B1 (en) | Friction reducing tool | |
US6562401B2 (en) | Method for making a stand-off device to prevent an oilfield tubular from contacting the side of the wellbore | |
US20070209839A1 (en) | System and method for reducing wear in drill pipe sections | |
CA2353249A1 (en) | Pipe centralizer and method of attachment | |
US4635968A (en) | Method and apparatus for protecting consecutive multiple variable diameter couplings | |
US4211440A (en) | Compensated blast joint for oil well production tubing | |
EP1749165A2 (en) | Threaded connection for oil field applications | |
CA1167834A (en) | Inner pipe support arrangement for double-walled pipe | |
US5398755A (en) | Stress rings for inflatable packers | |
US4381821A (en) | Blast joint and protection element therefor | |
US2664272A (en) | Coupling | |
CA2425425A1 (en) | Drill string member | |
USRE34017E (en) | Increased tensile strength variable diameter protective joint | |
US20030209857A1 (en) | Metal end cap seal with o-ring | |
US5133576A (en) | Carbide coated blast tube construction for use in oil and gas well completion across perforations | |
US4911479A (en) | Durable blast joint | |
JPH0598883A (en) | Retaining ring |
Legal Events
Date | Code | Title | Description |
---|---|---|---|
FEPP | Fee payment procedure |
Free format text: PAYOR NUMBER ASSIGNED (ORIGINAL EVENT CODE: ASPN); ENTITY STATUS OF PATENT OWNER: LARGE ENTITY |
|
AS | Assignment |
Owner name: CREDO TOOL COMPANY, OREGON Free format text: ASSIGNMENT OF ASSIGNORS INTEREST;ASSIGNOR:VERMONT AMERICAN CORPORATION;REEL/FRAME:007786/0882 Effective date: 19950101 |
|
FPAY | Fee payment |
Year of fee payment: 12 |
|
FEPP | Fee payment procedure |
Free format text: PAYER NUMBER DE-ASSIGNED (ORIGINAL EVENT CODE: RMPN); ENTITY STATUS OF PATENT OWNER: LARGE ENTITY Free format text: PAYOR NUMBER ASSIGNED (ORIGINAL EVENT CODE: ASPN); ENTITY STATUS OF PATENT OWNER: LARGE ENTITY |
|
AS | Assignment |
Owner name: CREDO TECHNOLOGY CORPORATION, DELAWARE Free format text: ASSIGNMENT OF ASSIGNORS INTEREST;ASSIGNOR:ROBERT BOSCH TOOL CORPORATION;REEL/FRAME:014615/0215 Effective date: 20030101 Owner name: ROBERT BOSCH TOOL CORPORATION, KENTUCKY Free format text: COMBINED MERGER AND CHANGE OF NAME;ASSIGNOR:VERMONT AMERICAN CORPORATION;REEL/FRAME:014609/0574 Effective date: 20021227 Owner name: VERMONT AMERICAN CORPORATION, DELAWARE Free format text: MERGER;ASSIGNOR:CREDO TOOL COMPANY;REEL/FRAME:014609/0549 Effective date: 20021227 |