Search Images Maps Play YouTube News Gmail Drive More »
Sign in
Screen reader users: click this link for accessible mode. Accessible mode has the same essential features but works better with your reader.

Patents

  1. Advanced Patent Search
Publication numberUS3191680 A
Publication typeGrant
Publication dateJun 29, 1965
Filing dateMar 14, 1962
Priority dateMar 14, 1962
Publication numberUS 3191680 A, US 3191680A, US-A-3191680, US3191680 A, US3191680A
InventorsVincent Renic P
Original AssigneePan American Petroleum Corp
Export CitationBiBTeX, EndNote, RefMan
External Links: USPTO, USPTO Assignment, Espacenet
Method of setting metallic liners in wells
US 3191680 A
Abstract  available in
Images(4)
Previous page
Next page
Claims  available in
Description  (OCR text may contain errors)

R. P. VINCENT 3,191,680

METHOD OF SETTING METALLIC LINERS IN WELLS 4 Sheets-Sheet 1 June 29, 1965 Filed March 14, 1962 RENIC P. VINCENT INVENTOR.

BYWWM ATTORNEY.

FIG. -1

June 29, 1965 Filed March 14. 1962 4 Sheets-Sheet 2- RENIC P VINC INVENT A TTORNE Y.

June 29, 1965 R. P. VINCENT 3,191,680

METHOD OF SETTING METALLIC LINERS IN WELLS Filed March 14, 1962 4 sheets-sheet s RENIC P. VINCENT INVENTOR.

FIG. 3

ATTORNEY June 29, 1965 R. P. VINCENT 3,191,630

METHOD OF SETTING METALLIC LINERS IN WELLS Filed March 14, 1962 4 Sheets-Sheet 4 ll i 70 RENIC P. VINCENT. I 72 INVENTIOR.

1 1 lz/fim FIG.-4

ATTORNEY.

United States Patent 3,191,680 MEHIUD 6F SETTING METALLIC LINERS IN WELLS Picnic 1. Vincent, Tulsa, Okla, assignor to Pan American Petroleum Corporation, Tulsa, Okla, a corporation of Delaware Filed Mar. 14, 1962, Ser. No.179,6il9 4 Claims. (Cl. 166-46) This invention relates to setting metallic liners in wells. More particularly it relates to setting such liners in previously unlined portions of Wells.

This is a continuation-in-part of my U.S. patent application No. 123,039, filed July 10, 1961, now abandoned. In that application a method and apparatus are described for placing a metallic liner in compressive stress within a section of casing in a well. I have now found that certain embodiments and variations of the method can be used for placing a very desirable form of liner in open hole to solve many of the problems in drilling, completing, and producing wells.

In drilling with liquid drilling fluids through vugular, cavernous, or fractured zones of earth formations, large volumes of the whole drilling fluid, not just filtrate, are often lost. A liner set over such a zone and sealed to formations above and below the zone would obviously stop loss of drilling fluids. For this application of a metal liner there are two principal requirements. First, the liner when set should have an internal diameter sufficient to pass a bit of the desired size, preferably the same bit used for drilling the unlined section of hole. This means the inside diameter of the liner should be no smaller than the inside diameter of the unlined hole. Second, a good seal must be established between the liner and the formation to avoid flow of drilling fluid behind the liner to the vugs, caverns, or fractures to which it was being lost before the liner was set.

Other possible applications of a liner during drilling operations with liquid drilling fluids include sealing ofi shales which tend to slough off into the well, and forming a conduit through enlarged well sections which tend to trap bit cuttings and then let these cuttings fall into the well at various inconvenient times.

When drilling a well with air or other gas, entry of water into the well sometimes compels abandonment of the gas with its advantage of rapid drilling rates. Again a liner which would seal off the water without reducing the well diameter would be very desirable. This application of a liner has the same two requirements as for those sealing-off Zones to which whole mud is lost.

After a well has been drilled and is ready for completion, several possible uses of my liner exist. For ex ample, a short section of liner can be set above the producing zone. The well can then be completed by running tubing or a small diameter casing and setting a packer between the liner and the tubing or casing. If desired, the space outside the casing or liner can then be filled with drilling fluids, oil, water or other materials frequently referred to as packer fluids.

In some cases it will be desirable to set a liner over the producing formation and then form openings through the liner by use of casing cutters, bullet perforators, jet perforators or the like. This is particularly desirable when an oil producing zone is thin and has water, gas or both closely associated with the oil. This technique is also particularly desirable as a method of placing a fracture only at exactly the desired level in a well by hydraulic fracturing technique. In these well completion operations, the liner need not be squeezed out until its internal diameter is the same as the well without the liner. The seal between the liner and the formation is ice obviously even more important, however, than in drilling operations.

Even after a well has been drilled, completed, and produced for a time, use of a liner is often advisable. For example, a gas cap may have formed resulting in excessive gas production. In this case, a liner may be set through the top of the producing formation to decrease gas production. In case of an active water drive the production of water into a Well may become excessive. In this case, a liner may be set opposite the bottom portion of the formation to decrease water production. These operations can probably best be considered as recompletion operations. Recompletion by one of the techniques mentioned above in connection with original completions may also be advisable.

All these cases are examples of instances in which a liner is required in a previously unlined section of the well. The term previously'unlined as used here obviously means the formations are still exposed to the well bore and have not been isolated by steel casing, cement, or the like. A section of well having a filter cake deposited from drilling fluid should be considered to be unlined for my purposes.

The problems described above are long-standing ones in the art of drilling, completing, and producing oil wells. Several solutions to the problems have been proposed including that suggested in U.S. Patent 1,233,888, Leonard. Leonard proposed setting a metallic liner in open hole by forming longitudinal corrugations in the wall of a tube to reduce its outer diameter so it could be lowered through a well or well casing of the same size as the original internal diameter of the tube. After the tube was lowered into the well, a .swage was driven through it to cause it to resume its original diameter and cylindrical shape. Small longitudinal cuts were formed in the bottom of the tube to divide the tube into a number of strips which were bent outwardly to act as anchors. Around the top of the tube a gasket was placed to form a more effective seal between the liner and formation.

The Leonard apparatus and method had several difficulties and was not accepted for general use. One problem was anchoring the corrugated tube so the swage could be driven through it. The tube could not be expanded anywhere except at the bottom of the well. Another problem in the Leonard system was getting the solid swage to the bottom of the well. In order for the swage to expand each section to the same diameter as the others, this swage had to be of the same external diameter as the internal diameter of the casing and well. As a result, running the swage to the new section of the liner was sometimes diificult.

Finally, it will be apparent that in expanding a section of liner to an internal diameter equal to the original internal diameter of the well, considerable crushing and cracking of the formation was necessary. The gasket provided by Leonard did not form an effective seal between the liner and this crushed and fractured formation.

The general plan of Leonard is excellent. Because of a few ditliculties, however, the plan has not been used to any "great extent in the 45 years since the Leonard patent issued. This is in spite of the continued existence of the problems outlined above, many of which Leonard recognized and described.

An object of this invention is to provide a method for setting a metallic liner in sealed engagement with the previously unlined wall of a well. More specifically, an object of the invention is to overcome the difiicuties with Leonards corrugated liner technique so this method and apparatus can be used to solve the problems which have existed for many years and which might be solved by a well-sealed, fully expanded metallic liner. Even more specifically, an object of the invention is to provide a method for expanding a longitudinally corrugated tube into a substantiallycylindrical shape to form a liner at any desired level in a well. Still another specific object is to provide a method for forming an efiective seal between a metallic liner and the wall of a well in which it is set.

As previously noted, I have now found that certain embodiments and variations of the apparatus and methods described in my US. patent application 123,039 can be used to accomplish the objects of my invention. Some of these are shown in the drawing in which FIGURE 1 is the same. as FIGURE 1 of my US. patent application 123,039 and shows a hydraulic means for expanding a liner using a double expanding head having a solid expanding cone and a collet spring head for making the final expansion. FIGURE 2 shows a modified section of FIGURE 1 in which the design of the expanding head is changed to provide a more positive final liner diameter of a desired preselected size. FIGURE 3 is a further modification of the design shown in FIGURE 2 but in which the hydraulic force is down rather than up. FIG- URE 4 is a design for setting a liner in the bottom of a well using the weight of a string of pipe to expand the liner.

Referring now to the drawing in more detail, in FIG- URE 1, the corrugated liner tube 11 is mounted between connector 12 and an expanding cone 13. The connector 12 includes a top collar portion 14 which is internally threaded to receive standard well tubing 15 which serves to lower the entire liner setting assembly into the well. Other hollow conduit, such as drill pipe, can, of course, be used if desired. The main body portion of connector 12 includes a central passage 16, the upper portion of which is threaded to receive and hold the top of a polished rod 17. A complete seal between the polished rod and connector 12 is assured by use of O-ring 10 in peripheral goove around passage 16. In the top of passage 16 a short pipe 22 with loose cap 23 is provided to prevent scale, dirt, and the like from the inside wall of the tubing from falling into the hydraulic system below.

Polished rod 17 includes a central bore 24 which connects with the interior of pipe 22. A piston 25 is mounted on the bottom of polished rod 17. The piston includes an internally threaded cap 26 for attachment to the externally threaded bottom portion of polished rod 17 The piston also includes flange 27 on which resilient cups 28 and 29 are mounted. Above top cup 25 a passage 30 is provided in the piston which is connected to the inner bore 24 of polished rod 17.

Piston 25 works in a cylinder 32 having a cap 33 through which polished rod 17 passes. Packing 34 is provided to form a seal between polished rod 17 and cap 33. Preferably, an O-ring 35 is provided between the cylinder 32 and cap 33 to insure a good seal between these members. Sleeve 36 rests on the top of cap 33 and supports expanding cone 13. Surrounding sleeve 36 is a collet head 37 with collet spring arms 38. The arms have an inner surface which is spaced from sleeve 36 to permit inward movement of the arms. The arms also have slots, not shown, between them to permit this same action. Near the tops of arms 38 are outwardly enlarged portions 40 which perform the final'forming action to force the corrugated liner into a substantially cylindrical shape as the cone and collet head are forced through the corrugated liner tube by the hydraulic piston and cylinder arrangement shown. Arms 43 are normally sprung out farther than shown in FIGURE 1. In this figure, the arms are shown as being restrained by projecting portions 41 which fit into a mating recess 42 in expanding cone 13. This permits lowering the assembly more easily through the well to the desired location.

In operation, the liner setting tool is assembled at the surface, as shown in FIGURE 1 and glass cloth saturated with resin is wrapped around the corrugated tube. The

assembly is lowered into the well in this condition to the location at which the liner is to be set. A liquid, such as oil, is then pumped into the tubing. The oil passes through the well tubing, pipe 22, polished rod 17, passages 3i! and into the cylinder 32 above piston 25. As the pressure increases, the pressure on cap 33 causes it to rise, carrying sleeve 36 and expander head 13 upwardly with respect to the polished rod. Upward movement of liner tube 11 is restrained by connector 12 attached to the top of the polished rod. Therefore, as expanding cone 13 rises, it expands corrugated liner tube 11.

As cone 13 passes upwardly through liner tube 11, the bottom of the tube eventually strikes the enlarged portions 46 of the collet head spring arms. When this happens, upward motion of the collet head is restrained and causes projections 41 to pull out of restraining recess 42. The arms then spring outwardly. As cap 33 on the hydraulic cylinder continues to rise, the cap comes in contact with the bottom of collet head 37, forcing it through liner tube 11. The spring arms complete the expansion of the liner tube out against the well wall, except, of course, for the sealing layer of glass fibers and resin between the liner and well wall.

When the upward movement of cap 33, collet head 37, and expanding cone 13 causes cone 13 to come into con tact with connector 12, the upward motion must, of course, stop. This is indicated by an increase of pressure required to inject liquid into the tubing. The expanding cone 13 and collet head 37 may then. be forced the remaining distance through the corrugated liner tube by simply lifting on the well tubing. This is possible because the frictional drag of the expanded portion of the liner against the well wall is sufficient to hold the liner down against the upward pull of the cone and collet head. In addition, if the liner is pressed back into the wall of the well, there will be a shoulder of the formation above the expanded liner to restrain upward movement of the corrugated tube. It will be apparent that after only a few inches of the liner have been expanded against and into the well wall, connector 12 is no longer needed to hold the liner down while the tube is being expanded.

An alternative procedure when cone 13 strikes connector 12 is to release the pressure on the tubing, raise the well tubing two or three feet, secure it firmly at the surface, and then resume injecting hydraulic fluid into the tubing. Raising the well tubing will lift connector 12 two or three feet above the top of the liner. Expanding cone 13 and collet head 37 can then be forced on through the liner tube by injecting hydraulic fluid through the tubing.

As soon as the cone and collet head have been pulled completely through the liner, the tubing and liner setting assembly are removed from the well. To avoid pulling a wet string, it is possible to inclue a break-off relief seal 69 in the well tubing 15 above cap 23. This seal can be broken oi by dropping a go-devil down the tubing. Breaking of the seal allows the liquid in the tubing to leak out as the tubing is pulled from the well.

The solid expanding element 13 in FIGURE 1 and similar elements in other figures are referred to as expanding cones for convenience. They are rarely actually cones, but are solids with surfaces which are surfaces of revolution about a central axis. The surface is tapered from a large end slightly smaller than the desired final diameter of the liner to a small end slightly smaller than the smallest diameter of the corrugated tube.

If a liner is to be set in a casing, the important factor is the pressure of the liner against the casing. It is important to have spring arms to apply this pressure regardless of minor variations in casing diameter. In a liner set in open hole, however, the most important factor is ordinarily the internal diameter of the liner. Therefore, a more positive means should be provided for insuring exactly the internal liner diameter which is desired. In addition, if the internal diameter of the liner is to be about the same as the original diameter of the well, it will be apparent that spring arms capable of applying a radial force sufiicient to expand the liner to this diameter will also exert approximately the same radial pressure on the well wall above the liner. This is not desirable. Therefore, use of the spring arms should ordinarily be limited to well completion operations where the final internal diameter of the liner is less than that of the well above the liner. In application of this sort, the spring arms move outwardly above the top of the liner. If properly designed with a large spring constant, the radial force on the well wall above the liner can be made very small.

Both the problem of insuring exactly the desired internal diameter of the liner and the problem of radial pressures on the well wall above the liner can be overcome by the design shown in FIGURE 2. In this design the expanding cone 43 is somewhat similar to the cone 13 in FIGURE 1 except for tapered surfaces 44 on the bottom. These surfaces are the faces of a truncated pyramid. The faces of this pyramid are all substantially congruent. The apex of the pyramid (formed by the extended faces of the truncated pyramid) lies substantially on the axis of sleeve 50 on which cone 43 is mounted. Tapered ends 45 of expanding arms 46 ride on tapered surface 44. These arms, preferably about 8 in number for a well 6 inches in diameter, have bulges 47 for the final expansion of the liner. Opposite the tapered end of each arm 46 is a hooked end which -fits into an annular groove 49 in sleeve 50 which fits over polished rod 17 and carries the expanding cone and arms. The arms are prevented from falling off sleeve 50 by collar 51. This collar is attached to sleeve 50 by set screws 52. The bottom of sleeve 50 rests on cap 33. The arrangement below this cap is as shown in FIGURE 1.

Toward the middle of sleeve 55 there are shoulders 53 and 54. Shoulder 53 supports expanding cone 43 when this cone is pressing against corrugated tube 11 and the tube is against connector 12. When the cone is not pressing against the tube, spring 55 which rests on shoulder 54 and presses against the base of cone 43, forces cone 43 upwardly permitting inward movement of arms 46. The spring should be sufficiently strong to support the weight of expanding cone 43 and the corrugated tube. At the top of sleeve 50 is retaining nut 56 to hold cone 43 on sleeve 59.

The corrugated tube in FIGURE 2 is made up of two parts. One is the usual corrugated mild steel tube which is identified as part 57. The other is portion 58 above part 57. Portion 53 is made of drillable material such as brass, aluminum alloy, or the like, having approximately the same strength as the steel tube. This is for reasons explained later. Preferably the two parts 57 and 58 are attached together as by welding, brazing, soldering, or the like.

In operation, the apparatus of FIGURE 2 is made up at the surface as shown in FIGURE 1 except that cap 33 is lowered sufficiently to bring retaining nut 56 into contact with cone 43. Glass cloth saturated with liquid settable resin is wrapped around the corrugated tube and the assembly is lowered into the well to the desired level. This step is simplified by the action of spring 55. When cap 33 is lowered, sleeve 50 goes with it carrying arms 46 downwardly because of hooked ends 48. Spring 55 acting against the bottom of cone 43 lifts the cone and corrugated tube with respect to sleeve 50. Tapered ends 45 on arms 46 are thus able to move inwardly to avoid applying any radial force against the well wall.

When the assembly is in the desired location in the well, hydraulic pressure is applied through hollow polished rod 17. Upward motion of cap 33 on the hydraulic cylinder then forces sleeve 50 upwardly with respect to rod 17, cone 43, and tube 11, compressing spring 55 until the base of cone 43 contacts shoulder 53. This motion also causes tapered surface 44 of cone 43 to contact tapered ends 45 of arms 46, forcing the arms out to a definite predetermined position as shown in FIGURE 2. Further application of hydraulic pressure then causes cone 43 and arms 46 to move upwardly through corrugated tube 11, expanding it out against and into the well wall.

As explained in connection with FIGURE 1, the expanding cone and arms must be pulled through the last few inches of the corrugated tube by lifting on the tubing or by resetting the tubing at a higher level and again applying hydraulic pressure. The action of the tool in the last few inches of the corrugated tube should be particularly noted. The only thing which holds arms 46 out against the corrugated tube is tapered surfaces 44 on cone 43. As soon as cone 43 passes the upper edge of tube 11 there is no force to hold cone 43 down against the action of spring 55. Cone 43 rises, therefore, releasing arms 46 so they can move inwardly. This is a very desirable action since it permits the tool to be easily withdrawn from the well. However, the action leaves a length of corrugated tube only partly expanded. The length of the partially expanded portion of the tube is equal to the distance between the outermost points on cone 43 and bulges 47 on arms 46. The upper portion 58 of tube 11 is made of an easily drillable material such as brass, aluminum alloy, or the like, and is of a length greater than the length of the partly expanded portion of the tube. If desired, this portion can be drilled with an ordinary rock bit or mill to the same internal diameter as the fully expanded portion of the tube.

Of course, it is possible to mill out a partially expanded portion of a steel liner. This involves an extra trip into the .well, however, so the operation should be avoided if possible. The drillable portion of the tube is particularly important if the liner is used in drilling operations. In this case the ordinary drilling bit can easily drill through the partially expanded portion of the liner if the liner is made of brass, for example. The bit can then continue drilling the earth formations. In the case of liners set in well completion operations, it is frequently unnecessary to remove the partially expanded portion of the liner, since the intended diameter in such cases is not so important.

If it is desired to leave the partially expanded portion of the liner on the bottom rather than the top of the tube, the apparatus shown in FIGURE 3 may be used. In this case the cone 43, arms 46, and sleeve 50 are much the same as in FIGURE 2 except that they are inverted. In addition spring 55 can be omitted since the force of gravity normally causes cone 43 to move away from arms 46, permitting the arms to move inwardly. In the apparatus of FIGURE 3 the corugated tube 11 is placed below cone 43 and is supported by plate 61 on the bottom of rod 17. The hydraulic pressure in this case is applied to a piston and hydraulic cylinder 62 above the tube-expanding assembly. A hole 63 may be provided int-he wall of cylinder 62 above the piston to permit entry and escape of fluids from the space above the piston. Preferably a cover 64 is provided for the cylinder to prevent entrance of large pieces of dirt, sand, or the like, into the cylinder.

Application of hydraulic pressure to the cylinder and piston in the arrangement of FIGURE 3 causes the expanding heads to move downwardly to expand the tube which is supported by plate 61. When cone 43 contacts plate 61, the tubing should be lowered a short distance,

after. which hydraulic pressure is again applied to force the expanding cone and arms the remaining distance through the tube. Plate 61 must, of course, be small enough in diameter to pass upwardly through the partially expanded portion on the bottom of the tube. That is, it must be of at least slightly smaller diameter than the largest diameter of the expanding cone.

FIGURE 4 shows apparatus adapted to set a liner in the bottom of a well. In this case the sleeve 50, arms 46, and cone 43 are mounted much as in FIGURE 3, except that there is no central rod 17. In FIGURE 4 sleeve 50 is supported directly by the tubing or drill pipe 15. The

corrugated tube 11 is mounted in this case on a supporting plate 70 by means of shear screws 71. Plate 79 is in turn mounted on the bottom of sleeve 56 and serves the double purpose of supporting the corrugated tube and expanding cone 43.

The corrugated tube is made up of steel portion 57 and drillable metal portion 58. Supporting disc 72 of drilla'ble metal such as brass, aluminum, cast iron, or the like, may be provided on the bottom of corrugated tube 11 to prevent excessive im-bedding of the tube in the bottom of the Well. Portion 58 should be long enough in this case to be sure that bulges 4-7 on arms 46 reach the bottom of portion 57 of the corrugated tube before supporting plate 74 strikes the bottom of the well or disc 72 if used.

In operation, the assembly of FIGURE 4 is lowered to the bottom of a well on tubing or drill pipe. When disc 72 reaches the bottom of the well, the Weight of the tubing or drill pipe on sleeve and plate 70 is transmitted to screws 71 causing them to shear. This permits cone 43 to contact tube 11. Further downward motion of the drill pipe and sleeve 59 causes tapered ends 45 on arms 46 to move outwardly on tapered surfaces 44 of cone 43 until shoulder 53 of sleeve 50 comes in contact with the base of cone 43. The weight of the string of tubing or drill pipe is thenapplied to cone 43 to force it downward through tube 11 to expand the tube partially. Further downward motion causes bulges on arms 46 to complete the expansion of portion 57 of the tube 11. If desired, several drill collars can be used above the expansion assembly to provide any desired amount of downward force to insure effective expansion of the tube.

When the string of tubing or drill pipe is lifted, cone 43 drops with respect to arms 46, permitting these to move inwardly so bulges 47 are not pressed against the well wall. The expansion assembly can then be easily removed from the well. An ordinary rock bit is then used to drill the partially expanded drillable portion 58 of the tube and drillable plate 72 after which drilling of the earth formations can continue.

It will be apparent that the apparatus shown in FIG- URES 2, 3 and 4 have several advantages in drilling operations. One of the principal advantages is that the bulges on the expanding arms extend to an exact predetermined point and no more or less. sign is such that the ends of the arms contact a shoulder on the solid expanding cone at the same time that the base of the cone contacts the shoulder on the sleeve. Both contacts thus control the relative positions of the cone and arms, thus determining the exact diameter to which the liner tube is expanded. Another advantage is that in spite of the ability to expand the liner to a diameter as great as that of the rest of the well, the expanding element does not press against the well wall when going into or coming out of the well.

In most operations the final diameter of the liner is definitely fixed by the apparatus shown in FIGURE 2, 3, and 4. One exception should be noted. If the radial pressure on the bulges on the expanding arms becomes excessive, this radial pressure is transmitted to the tapered ends of the arms and through these ends to the truncated pyramidal part of the solid expanding cone. It will be apparent that if the force on the arms becomes sufiiiciently high, the solid cone will be displaced along the sleeve to releive some of the radial pressure. Thus, while the tool ordinarily insures a liner diameter of the exact size desired, it does have a safety mechanism which permits it to yield in case of unusual conditions. To insure this action, the angle of faces 44 to the axis of the pyramid should be between about and about degrees preferably about 30 degrees.

The designs shown in FIGURES 2 and Sean be set at a level in a well other than at the bottom since the tools provide their own support for the end of the tube opposite the expanding elements. By using a drillable portion as Preferably, the de-.

'wall necessarily crushes and cracks the formation.

the last part of the corrugated tubing to be expanded, no unexpanded or partially expanded steel portion need be left in the well. In this regard, two comments should be made. Many drillers do not mind drilling a small amount of mild steel with a rock bit. These drillers would not be worried as long as the liner was expanded to substantially its entire length, that is to within about a foot of the end. Therefore, in many cases it is possible to use an allsteel corrugated tube. The second comment is that in some cases it would be desirable to make the entire corrugated tube of a material such as brass, aluminum alloy, or the like. Corrugated tubes of such materials may be not only more easily expanded into cylindrical form, but may also be desirable to combat special corrosive conditions or the like. It is also simpler to remove all or any part of such easily drillable materials than is the case of the liner is steel. It will be apparent that when reference is made to a malleable metal, this is intended to mean either a substantially pure metal such as aluminum or an alloy such as brass or steel.

Another very important advantage of my liner is the seal which is formed between the liner and the formation. As previously noted, expansion of the liner into the well As my liner is placed, however, the glass fiber mat, saturated with liquid settable resin, is squeezed between the tube and the formation. Some of the liquid resin is thus forced out of the glass mat and into the crushed and cracked formation, filling the cracks and the spaces between the crushed particles. When this resin sets to a hardened state, the crushed formation is consolidated into a solid impermeable mass and the cracks are sealed. Thus, there is little possibility of leakage through this crushed and cracked zone. If a resin such as an epoxy is used which bonds firmly to metals, there is no chance of leakage along the outside surface of the liner as often occurs when liners are sealed with Portland cement.

When my apparatus and method are used to complete or recomplete a well, as distinguished from use during drilling operations, the principal advantage is the nearly perfect seal between the liner and the well wall. This is particularly true if a fracturer is desired only at some exact level in the wall. In this case a short section, for example 20 feet, of liner can be set in the well. Perforations can be formed by bullet or jet perforators or a notch can be formed by abrasives or a casing cutter at exactly the desired level. Packers can be set above and below the opening and hydraulic pressure can be applied to form a fracture only at the desired level. The perfect seal avoids any danger that the fracturing liquid will flow up or down the well behind the liner to a naturally weak and, therefore, more easily fractured level of the formation. The same seal also prevents leakage of gas down along the liner to the opening opposite the fractured zone or upward along the liner and into the well if the liner ends a short distance above the gas zone. The same advantages also are present in case a water bearing zone is sealed off.

The possibility of setting the liner at any desired level above the bottom is also an essential element and an advantage of my apparatus and method as applied to well completions. Any of the embodiments of apparatus shown in FIGURES 1, 2, and 3 can be used for this purpose. It is true that the assembly shown in FIGURE 1 employs spring arms to expand the corrugated liner. This is permissible, however, in well completion operations since it is not necessary in this case for the inside diameter of the liner to be the same as, or larger than, the original diameter of the well. Therefore, the liner can be merely pressed firmly against the well wall to insure a good bond between the formation and the liner. The inside diameter of the liner in such a case will be somewhat smaller than the diameter of the unlined well. This permits the expanding arms to spring out as they pass the end of the liner, relieving most of the stress in the arms so they do not exert a strong radial pressure against the unlined well wall. The spring arms have the advantage of expanding the entire liner to the end rather than leaving a short, partially expanded section as when the apparatus of FIGURES 2 and 3 is used.

The length of the corrugated tube can be any length which can be set in a Well. A length of about feet has been'found to be a very convenient length for most purposes in open hole. Shorter lengths can be used in some cases; but in' order to obtain a highly effective seal, a liner of at least about 6 feet is generally advisable. In some cases much longer liner sections should be used such as 20 or 30 feet. Lengths greater than this are difiicult to handle due to the inconveniently long dimensions of the setting assembly.

Still longer lengths can be obtained by setting several shorter lengths separately end to end in the well. A single long length can be set by using a long polished rod through a long corrugated tube, but using a short hydraulic cylinder. A length of tube in then expanded equal to the length of the hydraulic cylinder. The cylinder position is then reset and the operation is repeated in the same way that the final few inches of the liner is expanded as explained previously. A longer length than 20 feet is sometimes needed to seal off all of an undesirable formation.

Still another technique for setting long sections of liner employs a casing packer such as the Baker Model E shown on page 576 of the Composite Catalog of Oil Field Equipment and Services, 1960-1961. Use of this packer makes possible the use of lighter tubing for manipulating the equipment in the well since part of the vertical thrust from the setting tool can be borne by the slips and packer element. The packer is ideally suited to setting long sections of liner since it can be raised and reset any number of times to permit use of a short hydraulic cylinder to expand almost any desired length of liner.

The thickness of the Wall of the corrugated tube is ordinarily about inch, particularly if the tube is made of mild steel. In the case of mild steel, the radius of curvature of the corrugations should be no less than about 3 times the thickness of the wall of the tube to avoid cracking of the steel when the tube is corrugated or expanded into cylindrical form. Steel liners should be Wellannealed after corrugation for the same reason. Steel walls thicker than inch make the corrugations very difficult to expand into cylindrical shape. In addition, if a liner is to have the same internal diameter as the original well, the formation must be forced back by an amount equal to the thickness of the liner plus the glass fibers on the Outside. This may not be possible in very hard formations with any reasonable amount of force applied to the expanding elements if the thickness of the steel liner is more than about A inch. A steel liner should be not much less than about 1 inch if it is to withstand the pressures and mechanical blows to which it will be subjected in a well. If a more malleable or ductile metal or alloy such as brass or aluminum is used, the thickness can be somewhat greater, particularly for well completions where the final internal'diameter is not critical. The radius of curvature of the corrngations can also be somewhat less than when steel is used. While the ridges and valleys of the corrugations are preferably parallel to the axis of the liner tube, it will be apparent that a tube in which the corrugations spiral around the tube to some degree may also be used. Preferably, however, the tube should be substantially-longitudinally corrugated. That is, a ridge of the corrugations should not Vary more than about an inch or two from a line parallel to the axis of the tube in a foot-long section of the tube.

The original internal diameter of the tube before corrugation should be at least about the desired final internal diameter for the re-expanded liner. The steps of corrugat- 1 IQ ing and re-expanding to cylindrical form ordinary stretch the liner circumference by about 2 percent. Thus, the internal cross-sectional perimeter of the corrugated liner may be slightly smaller than the desired final internal liner perimeter. The tube perimeter should be at least about 98 percent of the desired liner perimeter, however. Making the corrugated tube internal perimeter at least 98 percent as large as the final desired liner circumference insures that the expanding operation will not stretch the liner and split it. The internal perimeter of the tube should not be less than the greatest circumference of the expanding tool at'the bulges on the arms to. avoid the possibility of splitting the liner. The internal perimeter of the tube should not be more than about 10 percent greater than the desired final internal liner circumference to avoid excessive remanent corrugations in the liner as finally placed. An advantage of the resin filled glass mat is that the resin can fill smal-l channels left under remaining corrugations such as those at the partially expanded end of a liner. It is better, however, that this resin be available to penetrate the formation and insure a good seal and bond between the liner and formation. Therefore, the internal cross-sectional perimeter of the corrugated tube should be as near as possible to the final desired internal diameter. Certainly the perimeter should be no less than about 98 percent and no more than about percent of the desired internal perimeter of the liner. In this connection it should be noted again that the desired internal perimeter of the liner may be either the original well or hit diameter or even slightly larger, or it may be something less than the well diameter as when a lineris set in a well for wellcompletion purposes and the absolute diameter is not particularly critical.

When a corrugated tube is said to be expanded to substantially cylindrical shape it will be understood that this term is intended to include cases such as where the internal periphery of the tube is about 10 percent greater than the original well diameter. In this case there will be some remaining corrugations, but the liner may be con: sidered substantially cylindrical for my purposes. The same is usually true for the partially expanded end of a tube expanded by the apparatus of FIGURES 2 and 3. The solid cone in these cases expands the corrugated tube to within two or three tenths of an inch of the diameter established by the following arms. In such cases, the portion expanded by the solid cone alone can be considered for my purposes to be expanded to substantially cylindrical form or shape.

The glass fibers which are applied outside the liner and are saturated with liquid resin can be of several types. In selecting an appropriate type, the principal functions of the glass fibers should be borne in mind. The main function is to carry sufiicient resin to fill the space between the liner and formation and to penetrate the formation as far as possible. The glass fibers best adapted to this purpose are obtained in the form of cloth, woven of threads which are, in turn, spun from very fine glass fibers, preferably less than 0.001 inch in diameter. Mats in which the threads are stuck together with an adhesive or plastic may also be used. The glass mats may be simply wrapped around the outside of the corrugated liner and held in place by bands, threads, or wires. Preferably, the glass mat is attached by means of an adhesive to the corrugated surface of the liner. In this case, the resin may be applied with a blade or wire brush after the glass mat is attached to the liner surface. If the mat is simply wrapped around the liner, the resin is most conveniently applied to the glass mat, again with a blade or wire brush, before the mat is wrapped around the liner. In any case, the glass mat should be thoroughly saturated with the resin.

Any resin which will cure or set hard, either naturally or artificially, in the well may be employed. Typically, these resins are thermosetting resins, i.e., resins which are capable of undergoing a permanent physical change under the influence of well temperature or an artificially induced higher temperature. Polyester or epoxy resins are examples. Other suitable resins include urea, resorcinol, and phenol formaldehydes, and the like. Epon 828, an epoxy resin manufactured by Shell Chemical Company, is an example of a preferred epoxy resin. As is well known in this art, these resins may be combined and various catalysts or curing agents employed in various concentrations so that the setting or curing time or pot life for various well depths or various temperatures may be controlled. Versamid resin 140, a polyamide manufactured by General Mills, Inc., is an example of a preferred catalyst which, in the ratio of about 30 parts to 70 parts of the Epon 828 epoxy resin, has a pot life at room temperature of about 3 to 3 /2 hours. Such resins when set, i.e., when they are cured sufficiently to be self-supporting and relatively rigid, are referred to herein as plastics.

A lubricant should be applied to the inside surface of the corrugated liner tube to decrease frictional drag on the expanding cone and arms. Use of such a lubricant is not essential, but is recommended. The lubricant may be mineral oil, vegetable oil such as cottonseed oil, or animal oil such as sperm oil. It may also be in a more solid form, such as paraflin wax, beeswax, tallow, or the like. A preferred lubricant is made up of about 90 percent ozokerite, or its purified form ceresin wax, and about 10 percent of finely divided particles of malleable material, such as copper, lead, graphite,nutshells, or the like.

My invention will be better understood from the following example of setting a metallic liner in open hole. For this purpose a shallow well was drilled in the Oologah lime where it outcrops near Tulsa, Oklahoma. The well was drilled to a depth of 21 feet using a worn 4 As-inch bit which resulted in a well of about 4% inches. The assembly shown in FIGURE 1 was used to set a steel liner 6 feet long from a depth of about 11 feet to a depth of about 17 feet in this well. The original external diameter of the tube before corrugation was inches and the original internal diameter was 4% inches. Eight longitudinal corrugations were formed in the tube to reduce its maximum diameter to about 4 /2 inches. The corrugated tube was then carefully annealed. Before lowering the corrugated tube and expanding assembly into the well, a mat of glass fibers saturated with liquid resin was wrapped around the tube and fastened in place. The glass was a form known as woven roving. The liquid resin was an epoxy available under the trademark Epon 828. The catalyst was a polyamide known as Versamid 140. The outer unstressed diameter of the spring arms on the expanding head was about 4.7 inches.

To expand the tube in the well it was necessary to embed it into the well wall. This action plus the usual force required to expand the liner to its original cylindrical shape required a hydraulic pressure which varied between about 3,400 and about 7,000 pounds per square inch. Since the area of the piston was about square inches, this pressure produced a total vertical force between about 34,000 and 70,000 pounds. This high pressure may have been due in part to the slightly crooked nature of the well which increased the difficulty of pulling the tool through the liner.

After the liner was set, a caliper survey of the well was made using a special caliper accurate to about 0.005 inch. The results of the survey are presented in Table I. The caliper actually measured the well circumference from which the diameter was then calculated.

TABLE I Caliper survey stressed steel liner in open hole Depth (ft.): Hole size (in.)

Depth (ft): Hole size (in.)

Three points should be noted in Table I. The most important is that the internal diameter of the liner between ll and 17 feet is almost exactly the same as the internal diameter of the rest of the well. Second, the centerof the liner is slightly larger than the ends of the liner. This apparently is a characteristic of the system and has been observed in other cases. Third, the internal diameter of the liner seems to be slightly larger than the maximum diameter of the spring arms on the collet head. This observation also is not uncommon in the center of the liner. Apparently the expanding headapplies a leverage action which expands the liner following the expansion head to a diameter'slightly larger than the expanding head itself. After a liner has been expanded, the ends fit snugly against the expanding head when run a second time through the liner. Opposite the center of the liner, however, the expanding head fits loosely, there being several hundredths of an inch of clearance between the expanding head and the expanded liner. This does not, however, explain why the endsof the liner also seem to be slightly larger than the maximum unstressed diameter of the spring arms. A possible explanation is that caliper measurements were made only at one-foot intervals. The exact dimensions of the liner ends were not, therefore, measured. In any case, however, it is apparent that the liner was embedded into the formation to substantially its entire thickness. This is in spite of the very hard and strong nature of the Oologah lime.

After the liner had been set, the seal between the liner and the formation was tested. For this purpose two cuptype packers were mounted on tubing having an opening in the wall between the packers. The bottom packer opened upwardly and the top packer opened downwardly. The lips of the packers were set 19 inches apart in the well. The lip of the bottom packer. was set 9 inches below the bottom of the liner. Water was pumped into the tubing to apply hydraulic pressure to the well between the packers. This pressure was increased in steps starting at about 500 pounds per square inch and increasing in steps of 250 pounds per square inch. Noleakage was detected at any pressure up to and including 2,000 pounds per square inch. It was apparent, therefore, that any passages formed by crushing or cracking of the formation when the liner was expanded had been effectively sealed.

I claim:

1. A method for setting a metallic liner in sealed engagement with the wall of a previously unlined portion of a well comprising mounting a longitudinally corrugated tube of a malleable metal on a means for lowering said tube into said well, said tube having an internal crosssectional perimeter between about 98 and about percent as great as the final desired internal cross-sectional perimeter of said liner, applying around said corrugated tube amat of glass fibers, saturating said mat with a liquid resin capable of being set to a hardened state, lowering into said well to the desired level for said liner said tube with its surrounding layer of resin-saturated mat of glass fibers, expanding said tube into substantially cylindrical shape in contact with the wall of said previously unlined portion of said well while said resin is in a 13 liquid state, curing said resin to a hardened state, and withdrawing from said well said means for lowering said tube into said well, whereby a metallic liner is formed and bonded securely to earth formations penetrated by said well.

2. The method of claim 1 in which said malleable metal is steel.

3. The method of claim 1 in which said resin is an epoxy resin.

4. The method of claim 1 in which the internal crosssectional perimeter of said corrugated tube is substantially the same as the desired internal cross-sectional perimeter of said liner.

References Cited by the Examiner UNITED STATES PATENTS 1,301,285 4/19 Leonard 166-206 Simmons 166-206 Price 166-207 English 166-207 Bannister 166-46 Brown 166-46 Spearow 166-42 Teplitz et a1. 166-55 Kennedy 138-145 Matherne et al 138-145 Jennings 166-46 Condra 166/55 BENJAMIN HERSH, Primary Examiner.

15 CHARLES E. OCONNELL, Examiner.

Patent Citations
Cited PatentFiling datePublication dateApplicantTitle
US1301285 *Sep 1, 1916Apr 22, 1919Frank W A FinleyExpansible well-casing.
US1880218 *Oct 1, 1930Oct 4, 1932Simmons Richard PMethod of lining oil wells and means therefor
US1981525 *Dec 5, 1933Nov 20, 1934Price Bailey EMethod of and apparatus for drilling oil wells
US2214226 *Mar 29, 1939Sep 10, 1940English AaronMethod and apparatus useful in drilling and producing wells
US2583316 *Dec 9, 1947Jan 22, 1952Bannister Clyde EMethod and apparatus for setting a casing structure in a well hole or the like
US2762436 *Apr 22, 1949Sep 11, 1956Brown Cicero CMethods of lowering pipe within a well bore
US2821255 *Mar 30, 1956Jan 28, 1958Ralph SpearowSubformation oil production method
US2884066 *Jul 26, 1954Apr 28, 1959Gulf Research Development CoApparatus for applying outwardly directed forces to tubing
US2937665 *Oct 17, 1955May 24, 1960Trenton CorpPipe covering
US2966173 *Aug 21, 1957Dec 27, 1960Mc Graw Edison CoImpregnated fibrous member
US3028915 *Oct 27, 1958Apr 10, 1962Pan American Petroleum CorpMethod and apparatus for lining wells
US3039530 *Aug 26, 1959Jun 19, 1962Condra Elmo LCombination scraper and tube reforming device and method of using same
Referenced by
Citing PatentFiling datePublication dateApplicantTitle
US3669190 *Dec 21, 1970Jun 13, 1972Otis Eng CorpMethods of completing a well
US3712376 *Jul 26, 1971Jan 23, 1973Gearhart Owen IndustriesConduit liner for wellbore and method and apparatus for setting same
US3746091 *Jul 26, 1971Jul 17, 1973Owen HConduit liner for wellbore
US5348095 *Jun 7, 1993Sep 20, 1994Shell Oil CompanyMethod of creating a wellbore in an underground formation
US5366012 *Jun 7, 1993Nov 22, 1994Shell Oil CompanyMethod of completing an uncased section of a borehole
US5785120 *Nov 14, 1996Jul 28, 1998Weatherford/Lamb, Inc.Tubular patch
US5957195 *Oct 7, 1997Sep 28, 1999Weatherford/Lamb, Inc.Wellbore tool stroke indicator system and tubular patch
US6021850 *Oct 3, 1997Feb 8, 2000Baker Hughes IncorporatedDownhole pipe expansion apparatus and method
US6029748 *Oct 3, 1997Feb 29, 2000Baker Hughes IncorporatedMethod and apparatus for top to bottom expansion of tubulars
US6142230 *Oct 31, 1998Nov 7, 2000Weatherford/Lamb, Inc.Wellbore tubular patch system
US6325148Dec 22, 1999Dec 4, 2001Weatherford/Lamb, Inc.Tools and methods for use with expandable tubulars
US6328113Nov 15, 1999Dec 11, 2001Shell Oil CompanyIsolation of subterranean zones
US6425444Dec 22, 1999Jul 30, 2002Weatherford/Lamb, Inc.Method and apparatus for downhole sealing
US6431282 *Apr 5, 2000Aug 13, 2002Shell Oil CompanyMethod for annular sealing
US6446323Dec 22, 1999Sep 10, 2002Weatherford/Lamb, Inc.Profile formation
US6446724May 3, 2001Sep 10, 2002Baker Hughes IncorporatedHanging liners by pipe expansion
US6454013Nov 2, 1998Sep 24, 2002Weatherford/Lamb, Inc.Expandable downhole tubing
US6457533Jul 13, 1998Oct 1, 2002Weatherford/Lamb, Inc.Downhole tubing
US6470966May 7, 2001Oct 29, 2002Robert Lance CookApparatus for forming wellbore casing
US6497289Dec 3, 1999Dec 24, 2002Robert Lance CookMethod of creating a casing in a borehole
US6513588Sep 13, 2000Feb 4, 2003Weatherford/Lamb, Inc.Downhole apparatus
US6527049Dec 22, 1999Mar 4, 2003Weatherford/Lamb, Inc.Apparatus and method for isolating a section of tubing
US6543552Dec 22, 1999Apr 8, 2003Weatherford/Lamb, Inc.Method and apparatus for drilling and lining a wellbore
US6557640Jun 7, 2000May 6, 2003Shell Oil CompanyLubrication and self-cleaning system for expansion mandrel
US6561227May 9, 2001May 13, 2003Shell Oil CompanyWellbore casing
US6561271Mar 1, 2002May 13, 2003Baker Hughes IncorporatedHanging liners by pipe expansion
US6568471Feb 24, 2000May 27, 2003Shell Oil CompanyLiner hanger
US6575240Feb 24, 2000Jun 10, 2003Shell Oil CompanySystem and method for driving pipe
US6575250Nov 15, 2000Jun 10, 2003Shell Oil CompanyExpanding a tubular element in a wellbore
US6598677May 20, 1999Jul 29, 2003Baker Hughes IncorporatedHanging liners by pipe expansion
US6598678Nov 13, 2000Jul 29, 2003Weatherford/Lamb, Inc.Apparatus and methods for separating and joining tubulars in a wellbore
US6604763Apr 26, 2000Aug 12, 2003Shell Oil CompanyExpandable connector
US6629567Dec 7, 2001Oct 7, 2003Weatherford/Lamb, Inc.Method and apparatus for expanding and separating tubulars in a wellbore
US6631759Feb 12, 2002Oct 14, 2003Shell Oil CompanyApparatus for radially expanding a tubular member
US6631760May 9, 2001Oct 14, 2003Shell Oil CompanyTie back liner for a well system
US6631765Nov 14, 2002Oct 14, 2003Baker Hughes IncorporatedHanging liners by pipe expansion
US6631769Feb 15, 2002Oct 14, 2003Shell Oil CompanyMethod of operating an apparatus for radially expanding a tubular member
US6634431Oct 3, 2001Oct 21, 2003Robert Lance CookIsolation of subterranean zones
US6640903Mar 10, 2000Nov 4, 2003Shell Oil CompanyForming a wellbore casing while simultaneously drilling a wellbore
US6684947Feb 20, 2002Feb 3, 2004Shell Oil CompanyApparatus for radially expanding a tubular member
US6688400May 14, 2002Feb 10, 2004Weatherford/Lamb, Inc.Downhole sealing
US6702029Dec 22, 1999Mar 9, 2004Weatherford/Lamb, Inc.Tubing anchor
US6705395Feb 12, 2002Mar 16, 2004Shell Oil CompanyWellbore casing
US6708769May 4, 2001Mar 23, 2004Weatherford/Lamb, Inc.Apparatus and methods for forming a lateral wellbore
US6712154Oct 18, 2001Mar 30, 2004Enventure Global TechnologyIsolation of subterranean zones
US6725919Sep 25, 2001Apr 27, 2004Shell Oil CompanyForming a wellbore casing while simultaneously drilling a wellbore
US6732806 *Jan 29, 2002May 11, 2004Weatherford/Lamb, Inc.One trip expansion method and apparatus for use in a wellbore
US6739392Sep 25, 2001May 25, 2004Shell Oil CompanyForming a wellbore casing while simultaneously drilling a wellbore
US6742606 *Feb 11, 2003Jun 1, 2004Weatherford/Lamb, Inc.Method and apparatus for drilling and lining a wellbore
US6745845Dec 10, 2001Jun 8, 2004Shell Oil CompanyIsolation of subterranean zones
US6752215Oct 2, 2001Jun 22, 2004Weatherford/Lamb, Inc.Method and apparatus for expanding and separating tubulars in a wellbore
US6758278Sep 25, 2001Jul 6, 2004Shell Oil CompanyForming a wellbore casing while simultaneously drilling a wellbore
US6823937Feb 10, 2000Nov 30, 2004Shell Oil CompanyWellhead
US6851475Mar 14, 2003Feb 8, 2005Weatherford/Lamb, Inc.Apparatus and methods for separating and joining tubulars in a wellbore
US6857473Mar 7, 2002Feb 22, 2005Shell Oil CompanyMethod of coupling a tubular member to a preexisting structure
US6857487Dec 30, 2002Feb 22, 2005Weatherford/Lamb, Inc.Drilling with concentric strings of casing
US6892819Sep 25, 2001May 17, 2005Shell Oil CompanyForming a wellbore casing while simultaneously drilling a wellbore
US6896075Oct 11, 2002May 24, 2005Weatherford/Lamb, Inc.Apparatus and methods for drilling with casing
US6899181Jan 22, 2003May 31, 2005Weatherford/Lamb, Inc.Methods and apparatus for expanding a tubular within another tubular
US6899186Dec 13, 2002May 31, 2005Weatherford/Lamb, Inc.Apparatus and method of drilling with casing
US6915852Jul 24, 2003Jul 12, 2005Baker Hughes IncorporatedHanging liners by pipe expansion
US6920935Aug 9, 2002Jul 26, 2005Weatherford/Lamb, Inc.Expandable downhole tubing
US6923261Dec 16, 2002Aug 2, 2005Weatherford/Lamb, Inc.Apparatus and method for expanding a tubular
US6942036Apr 9, 2002Sep 13, 2005Baker Hughes IncorporatedTreating apparatus and method for expandable screen system
US6953096Dec 31, 2002Oct 11, 2005Weatherford/Lamb, Inc.Expandable bit with secondary release device
US6966370Feb 20, 2002Nov 22, 2005Shell Oil CompanyApparatus for actuating an annular piston
US6968618May 12, 2003Nov 29, 2005Shell Oil CompanyExpandable connector
US6976539Sep 11, 2003Dec 20, 2005Weatherford/Lamb, Inc.Tubing anchor
US6976541Jan 22, 2003Dec 20, 2005Shell Oil CompanyLiner hanger with sliding sleeve valve
US6994176Mar 5, 2004Feb 7, 2006Weatherford/Lamb, Inc.Adjustable rotating guides for spider or elevator
US7004257Nov 29, 2004Feb 28, 2006Weatherford/Lamb, IncApparatus and methods for separating and joining tubulars in a wellbore
US7004260Jul 18, 2002Feb 28, 2006Shell Oil CompanyMethod of sealing an annulus
US7004264Mar 14, 2003Feb 28, 2006Weatherford/Lamb, Inc.Bore lining and drilling
US7011161Oct 1, 2002Mar 14, 2006Shell Oil CompanyStructural support
US7013997Dec 15, 2003Mar 21, 2006Weatherford/Lamb, Inc.Methods and apparatus for cementing drill strings in place for one pass drilling and completion of oil and gas wells
US7021390Apr 18, 2003Apr 4, 2006Shell Oil CompanyTubular liner for wellbore casing
US7028770Sep 30, 2002Apr 18, 2006Baker Hughes, IncorporatedTubular expansion apparatus and method
US7036582Oct 1, 2002May 2, 2006Shell Oil CompanyExpansion cone for radially expanding tubular members
US7036610Jul 6, 2002May 2, 2006Weatherford / Lamb, Inc.Apparatus and method for completing oil and gas wells
US7040396Feb 20, 2002May 9, 2006Shell Oil CompanyApparatus for releasably coupling two elements
US7040420Nov 19, 2003May 9, 2006Weatherford/Lamb, Inc.Methods and apparatus for cementing drill strings in place for one pass drilling and completion of oil and gas wells
US7044218Oct 1, 2002May 16, 2006Shell Oil CompanyApparatus for radially expanding tubular members
US7044221Feb 20, 2002May 16, 2006Shell Oil CompanyApparatus for coupling a tubular member to a preexisting structure
US7048050Oct 2, 2003May 23, 2006Weatherford/Lamb, Inc.Method and apparatus for cementing drill strings in place for one pass drilling and completion of oil and gas wells
US7048062Oct 1, 2002May 23, 2006Shell Oil CompanyMethod of selecting tubular members
US7048067Oct 31, 2000May 23, 2006Shell Oil CompanyWellbore casing repair
US7055608Apr 18, 2003Jun 6, 2006Shell Oil CompanyForming a wellbore casing while simultaneously drilling a wellbore
US7063142Feb 15, 2002Jun 20, 2006Shell Oil CompanyMethod of applying an axial force to an expansion cone
US7066284Nov 13, 2002Jun 27, 2006Halliburton Energy Services, Inc.Method and apparatus for a monodiameter wellbore, monodiameter casing, monobore, and/or monowell
US7073598Jul 23, 2003Jul 11, 2006Weatherford/Lamb, Inc.Apparatus and methods for tubular makeup interlock
US7077211Jan 29, 2004Jul 18, 2006Shell Oil CompanyMethod of creating a casing in a borehole
US7077213Oct 1, 2002Jul 18, 2006Shell Oil CompanyExpansion cone for radially expanding tubular members
US7083005May 31, 2005Aug 1, 2006Weatherford/Lamb, Inc.Apparatus and method of drilling with casing
US7090005Sep 15, 2004Aug 15, 2006Baker Hughes IncorporatedTubular expansion apparatus and method
US7090021Mar 16, 2004Aug 15, 2006Bernd-Georg PietrasApparatus for connecting tublars using a top drive
US7090023May 9, 2005Aug 15, 2006Weatherford/Lamb, Inc.Apparatus and methods for drilling with casing
US7093653Oct 24, 2003Aug 22, 2006Weatherford/LambDownhole filter
US7093675Aug 1, 2001Aug 22, 2006Weatherford/Lamb, Inc.Drilling method
US7096982Feb 27, 2004Aug 29, 2006Weatherford/Lamb, Inc.Drill shoe
US7100684Dec 18, 2002Sep 5, 2006Enventure Global TechnologyLiner hanger with standoffs
US7100685Jun 13, 2003Sep 5, 2006Enventure Global TechnologyMono-diameter wellbore casing
US7100710Dec 18, 2003Sep 5, 2006Weatherford/Lamb, Inc.Methods and apparatus for cementing drill strings in place for one pass drilling and completion of oil and gas wells
US7100713Apr 2, 2001Sep 5, 2006Weatherford/Lamb, Inc.Expandable apparatus for drift and reaming borehole
US7108061Oct 25, 2002Sep 19, 2006Shell Oil CompanyExpander for a tapered liner with a shoe
US7108072Mar 5, 2003Sep 19, 2006Shell Oil CompanyLubrication and self-cleaning system for expansion mandrel
US7108084Dec 24, 2003Sep 19, 2006Weatherford/Lamb, Inc.Methods and apparatus for cementing drill strings in place for one pass drilling and completion of oil and gas wells
US7117940Mar 8, 2004Oct 10, 2006Shell Oil CompanyExpander for expanding a tubular element
US7117957May 25, 2004Oct 10, 2006Weatherford/Lamb, Inc.Methods for drilling and lining a wellbore
US7121337Jun 1, 2005Oct 17, 2006Shell Oil CompanyApparatus for expanding a tubular member
US7121352Jul 14, 2003Oct 17, 2006Enventure Global TechnologyIsolation of subterranean zones
US7124821Jul 18, 2005Oct 24, 2006Weatherford/Lamb, Inc.Apparatus and method for expanding a tubular
US7124830Jul 26, 2005Oct 24, 2006Weatherford/Lamb, Inc.Methods of placing expandable downhole tubing in a wellbore
US7128154Jan 29, 2004Oct 31, 2006Weatherford/Lamb, Inc.Single-direction cementing plug
US7128161Sep 20, 2005Oct 31, 2006Weatherford/Lamb, Inc.Apparatus and methods for facilitating the connection of tubulars using a top drive
US7131498Mar 8, 2004Nov 7, 2006Shell Oil CompanyExpander for expanding a tubular element
US7131505Feb 22, 2005Nov 7, 2006Weatherford/Lamb, Inc.Drilling with concentric strings of casing
US7137454May 13, 2005Nov 21, 2006Weatherford/Lamb, Inc.Apparatus for facilitating the connection of tubulars using a top drive
US7140428Mar 8, 2004Nov 28, 2006Shell Oil CompanyExpander for expanding a tubular element
US7140445Mar 5, 2004Nov 28, 2006Weatherford/Lamb, Inc.Method and apparatus for drilling with casing
US7144243Nov 27, 2002Dec 5, 2006Weatherford/Lamb, Inc.Tubing expansion
US7146702Mar 7, 2005Dec 12, 2006Shell Oil CompanyMethod and apparatus for forming a mono-diameter wellbore casing
US7147053Aug 13, 2004Dec 12, 2006Shell Oil CompanyWellhead
US7147068Dec 5, 2003Dec 12, 2006Weatherford / Lamb, Inc.Methods and apparatus for cementing drill strings in place for one pass drilling and completion of oil and gas wells
US7159665Jul 19, 2002Jan 9, 2007Shell Oil CompanyWellbore casing
US7159667Feb 2, 2004Jan 9, 2007Shell Oil CompanyMethod of coupling a tubular member to a preexisting structure
US7165634Oct 2, 2003Jan 23, 2007Weatherford/Lamb, Inc.Method and apparatus for cementing drill strings in place for one pass drilling and completion of oil and gas wells
US7168496Jun 26, 2002Jan 30, 2007Eventure Global TechnologyLiner hanger
US7168497Dec 30, 2003Jan 30, 2007Weatherford/Lamb, Inc.Downhole sealing
US7168499Sep 10, 2004Jan 30, 2007Shell Oil CompanyRadial expansion of tubular members
US7172019Mar 7, 2005Feb 6, 2007Shell Oil CompanyMethod and apparatus for forming a mono-diameter wellbore casing
US7172021Nov 3, 2004Feb 6, 2007Shell Oil CompanyLiner hanger with sliding sleeve valve
US7172024Mar 31, 2003Feb 6, 2007Shell Oil CompanyMono-diameter wellbore casing
US7172027Jun 10, 2003Feb 6, 2007Weatherford/Lamb, Inc.Expanding tubing
US7174964Jul 22, 2003Feb 13, 2007Shell Oil CompanyWellhead with radially expanded tubulars
US7185710Jun 13, 2003Mar 6, 2007Enventure Global TechnologyMono-diameter wellbore casing
US7188687Jul 27, 2004Mar 13, 2007Weatherford/Lamb, Inc.Downhole filter
US7191840Mar 5, 2004Mar 20, 2007Weatherford/Lamb, Inc.Casing running and drilling system
US7195061Jun 2, 2005Mar 27, 2007Shell Oil CompanyApparatus for expanding a tubular member
US7195064Aug 13, 2003Mar 27, 2007Enventure Global TechnologyMono-diameter wellbore casing
US7198100Jun 2, 2005Apr 3, 2007Shell Oil CompanyApparatus for expanding a tubular member
US7201223Mar 1, 2005Apr 10, 2007Shell Oil CompanyMethod and apparatus for forming a mono-diameter wellbore casing
US7204007Mar 4, 2005Apr 17, 2007Shell Oil CompanyMethod and apparatus for forming a mono-diameter wellbore casing
US7213656Apr 26, 2004May 8, 2007Weatherford/Lamb, Inc.Apparatus and method for facilitating the connection of tubulars using a top drive
US7216701Jun 1, 2005May 15, 2007Shell Oil CompanyApparatus for expanding a tubular member
US7216727Dec 21, 2000May 15, 2007Weatherford/Lamb, Inc.Drilling bit for drilling while running casing
US7219744Nov 29, 2005May 22, 2007Weatherford/Lamb, Inc.Method and apparatus for connecting tubulars using a top drive
US7225879Jun 15, 2005Jun 5, 2007Halliburton Energy Services, Inc.Method and apparatus for a monodiameter wellbore, monodiameter casing, monobore, and/or monowell
US7228901Dec 1, 2005Jun 12, 2007Weatherford/Lamb, Inc.Method and apparatus for cementing drill strings in place for one pass drilling and completion of oil and gas wells
US7231985Sep 10, 2004Jun 19, 2007Shell Oil CompanyRadial expansion of tubular members
US7234531Sep 19, 2002Jun 26, 2007Enventure Global Technology, LlcMono-diameter wellbore casing
US7234542Feb 9, 2006Jun 26, 2007Weatherford/Lamb, Inc.Methods and apparatus for cementing drill strings in place for one pass drilling and completion of oil and gas wells
US7240728Sep 25, 2001Jul 10, 2007Shell Oil CompanyExpandable tubulars with a radial passage and wall portions with different wall thicknesses
US7240729Jan 30, 2004Jul 10, 2007Shell Oil CompanyApparatus for expanding a tubular member
US7243722 *Jan 28, 2002Jul 17, 2007E2Tech LimitedExpander device
US7246667Sep 27, 2004Jul 24, 2007Shell Oil CompanyRadial expansion of tubular members
US7258168Jul 27, 2001Aug 21, 2007Enventure Global Technology L.L.C.Liner hanger with slip joint sealing members and method of use
US7264067Oct 1, 2004Sep 4, 2007Weatherford/Lamb, Inc.Method of drilling and completing multiple wellbores inside a single caisson
US7267175Mar 17, 2005Sep 11, 2007Weatherford/Lamb, Inc.Apparatus and methods for forming a lateral wellbore
US7270188Nov 22, 2002Sep 18, 2007Shell Oil CompanyRadial expansion of tubular members
US7275601Sep 28, 2004Oct 2, 2007Shell Oil CompanyRadial expansion of tubular members
US7284617May 20, 2004Oct 23, 2007Weatherford/Lamb, Inc.Casing running head
US7290605Dec 10, 2002Nov 6, 2007Enventure Global TechnologySeal receptacle using expandable liner hanger
US7290616Jun 26, 2002Nov 6, 2007Enventure Global Technology, L.L.C.Liner hanger
US7299881Sep 27, 2004Nov 27, 2007Shell Oil CompanyRadial expansion of tubular members
US7303022Apr 27, 2004Dec 4, 2007Weatherford/Lamb, Inc.Wired casing
US7308755Mar 4, 2005Dec 18, 2007Shell Oil CompanyApparatus for forming a mono-diameter wellbore casing
US7308944Oct 7, 2003Dec 18, 2007Weatherford/Lamb, Inc.Expander tool for use in a wellbore
US7311148Feb 9, 2004Dec 25, 2007Weatherford/Lamb, Inc.Methods and apparatus for wellbore construction and completion
US7325602Sep 28, 2006Feb 5, 2008Shell Oil CompanyMethod and apparatus for forming a mono-diameter wellbore casing
US7325610Mar 5, 2004Feb 5, 2008Weatherford/Lamb, Inc.Methods and apparatus for handling and drilling with tubulars or casing
US7334650Feb 2, 2004Feb 26, 2008Weatherford/Lamb, Inc.Apparatus and methods for drilling a wellbore using casing
US7341117Jan 22, 2007Mar 11, 2008Halliburton Energy Services, Inc.Method and apparatus for a monodiameter wellbore, monodiameter casing, monobore, and/or monowell
US7350563Aug 14, 2002Apr 1, 2008Enventure Global Technology, L.L.C.System for lining a wellbore casing
US7350564May 20, 2005Apr 1, 2008Enventure Global Technology, L.L.C.Mono-diameter wellbore casing
US7357188Feb 23, 2000Apr 15, 2008Shell Oil CompanyMono-diameter wellbore casing
US7357190Sep 28, 2004Apr 15, 2008Shell Oil CompanyRadial expansion of tubular members
US7360591Apr 17, 2003Apr 22, 2008Enventure Global Technology, LlcSystem for radially expanding a tubular member
US7360594Mar 5, 2004Apr 22, 2008Weatherford/Lamb, Inc.Drilling with casing latch
US7363690Mar 2, 2005Apr 29, 2008Shell Oil CompanyMethod and apparatus for forming a mono-diameter wellbore casing
US7363691Mar 3, 2005Apr 29, 2008Shell Oil CompanyMethod and apparatus for forming a mono-diameter wellbore casing
US7363984May 12, 2003Apr 29, 2008Enventure Global Technology, LlcSystem for radially expanding a tubular member
US7370707Apr 5, 2004May 13, 2008Weatherford/Lamb, Inc.Method and apparatus for handling wellbore tubulars
US7373990Jun 8, 2004May 20, 2008Weatherford/Lamb, Inc.Method and apparatus for expanding and separating tubulars in a wellbore
US7377326Aug 18, 2003May 27, 2008Enventure Global Technology, L.L.C.Magnetic impulse applied sleeve method of forming a wellbore casing
US7380593Nov 27, 2002Jun 3, 2008Shell Oil CompanyExpandable tubes with overlapping end portions
US7383889Nov 12, 2002Jun 10, 2008Enventure Global Technology, LlcMono diameter wellbore casing
US7398832May 5, 2003Jul 15, 2008Enventure Global Technology, LlcMono-diameter wellbore casing
US7404444Aug 18, 2003Jul 29, 2008Enventure Global TechnologyProtective sleeve for expandable tubulars
US7410000May 20, 2005Aug 12, 2008Enventure Global Technology, Llc.Mono-diameter wellbore casing
US7413020Mar 5, 2004Aug 19, 2008Weatherford/Lamb, Inc.Full bore lined wellbores
US7416027Aug 13, 2002Aug 26, 2008Enventure Global Technology, LlcAdjustable expansion cone assembly
US7419009Mar 18, 2005Sep 2, 2008Shell Oil CompanyApparatus for radially expanding and plastically deforming a tubular member
US7424918Aug 18, 2003Sep 16, 2008Enventure Global Technology, L.L.C.Interposed joint sealing layer method of forming a wellbore casing
US7434618Jun 1, 2005Oct 14, 2008Shell Oil CompanyApparatus for expanding a tubular member
US7438132Apr 23, 2003Oct 21, 2008Shell Oil CompanyConcentric pipes expanded at the pipe ends and method of forming
US7438133Feb 26, 2004Oct 21, 2008Enventure Global Technology, LlcApparatus and method for radially expanding and plastically deforming a tubular member
US7493946Apr 11, 2007Feb 24, 2009Mohawk Energy Ltd.Apparatus for radial expansion of a tubular
US7497255Mar 26, 2007Mar 3, 2009Mohawk Energy Ltd.High performance expandable tubular system
US7503393Jan 26, 2004Mar 17, 2009Enventure Global Technology, Inc.Lubrication system for radially expanding tubular members
US7503397Jul 29, 2005Mar 17, 2009Weatherford/Lamb, Inc.Apparatus and methods of setting and retrieving casing with drilling latch and bottom hole assembly
US7509722Mar 5, 2003Mar 31, 2009Weatherford/Lamb, Inc.Positioning and spinning device
US7513313Sep 22, 2003Apr 7, 2009Enventure Global Technology, LlcBottom plug for forming a mono diameter wellbore casing
US7516790Jan 9, 2003Apr 14, 2009Enventure Global Technology, LlcMono-diameter wellbore casing
US7546881 *Oct 25, 2006Jun 16, 2009Enventure Global Technology, LlcApparatus for radially expanding and plastically deforming a tubular member
US7552776Oct 13, 2005Jun 30, 2009Enventure Global Technology, LlcAnchor hangers
US7556092Feb 15, 2002Jul 7, 2009Enventure Global Technology, LlcFlow control system for an apparatus for radially expanding tubular members
US7559365Nov 12, 2002Jul 14, 2009Enventure Global Technology, LlcCollapsible expansion cone
US7571774Aug 18, 2003Aug 11, 2009Eventure Global TechnologySelf-lubricating expansion mandrel for expandable tubular
US7571777Dec 10, 2007Aug 11, 2009Halliburton Energy Services, Inc.Method and apparatus for a monodiameter wellbore, monodiameter casing, monobore, and/or monowell
US7597140 *May 3, 2004Oct 6, 2009Shell Oil CompanyExpansion device for expanding a pipe
US7603758Feb 14, 2001Oct 20, 2009Shell Oil CompanyMethod of coupling a tubular member
US7617866Sep 8, 2005Nov 17, 2009Weatherford/Lamb, Inc.Methods and apparatus for connecting tubulars using a top drive
US7640976Nov 7, 2006Jan 5, 2010Mohawk Energy Ltd.Method and apparatus for downhole tubular expansion
US7650944Jul 11, 2003Jan 26, 2010Weatherford/Lamb, Inc.Vessel for well intervention
US7665532Oct 19, 2007Feb 23, 2010Shell Oil CompanyPipeline
US7681636 *Jul 20, 2006Mar 23, 2010Shell Oil CompanyPipe expander
US7694402Aug 1, 2005Apr 13, 2010Packless Metal Hose, Inc.Method for forming a lined conduit
US7712522Apr 3, 2007May 11, 2010Enventure Global Technology, LlcExpansion cone and system
US7712523Mar 14, 2003May 11, 2010Weatherford/Lamb, Inc.Top drive casing system
US7730965Jan 30, 2006Jun 8, 2010Weatherford/Lamb, Inc.Retractable joint and cementing shoe for use in completing a wellbore
US7739917Aug 18, 2003Jun 22, 2010Enventure Global Technology, LlcPipe formability evaluation for expandable tubulars
US7740076Mar 4, 2003Jun 22, 2010Enventure Global Technology, L.L.C.Protective sleeve for threaded connections for expandable liner hanger
US7775290Apr 15, 2004Aug 17, 2010Enventure Global Technology, LlcApparatus for radially expanding and plastically deforming a tubular member
US7793721Mar 11, 2004Sep 14, 2010Eventure Global Technology, LlcApparatus for radially expanding and plastically deforming a tubular member
US7819185Aug 12, 2005Oct 26, 2010Enventure Global Technology, LlcExpandable tubular
US7857052May 11, 2007Dec 28, 2010Weatherford/Lamb, Inc.Stage cementing methods used in casing while drilling
US7878240 *Jun 5, 2008Feb 1, 2011Baker Hughes IncorporatedDownhole swaging system and method
US7886831Aug 6, 2007Feb 15, 2011Enventure Global Technology, L.L.C.Apparatus for radially expanding and plastically deforming a tubular member
US7918284Mar 31, 2003Apr 5, 2011Enventure Global Technology, L.L.C.Protective sleeve for threaded connections for expandable liner hanger
US7921925May 12, 2008Apr 12, 2011Weatherford/Lamb, Inc.Method and apparatus for expanding and separating tubulars in a wellbore
US7926160 *Aug 1, 2005Apr 19, 2011Packless IndustriesMethod of forming a lined tubular member
US7938201Feb 28, 2006May 10, 2011Weatherford/Lamb, Inc.Deep water drilling with casing
US7992644Dec 17, 2007Aug 9, 2011Weatherford/Lamb, Inc.Mechanical expansion system
US8075813Dec 5, 2006Dec 13, 2011Weatherford/Lamb, Inc.Tubing expansion
US8276689May 18, 2007Oct 2, 2012Weatherford/Lamb, Inc.Methods and apparatus for drilling with casing
US8641407Dec 13, 2011Feb 4, 2014Weatherford/Lamb, Inc.Tubing expansion
US8800669Apr 20, 2012Aug 12, 2014Weatherford/Lamb, Inc.System and method to expand tubulars below restrictions
USRE42877Jul 9, 2010Nov 1, 2011Weatherford/Lamb, Inc.Methods and apparatus for wellbore construction and completion
CN101238273BJul 20, 2006Jan 11, 2012国际壳牌研究有限公司Pipe expander
WO1993025800A1 *Jun 8, 1993Dec 23, 1993Shell Canada LtdMethod of completing an uncased section of a borehole
WO2003029608A1 *Sep 26, 2002Apr 10, 2003Robert Joe CoonMethod and apparatus for expanding and separating tubulars in a wellbore
WO2003029609A1 *Sep 30, 2002Apr 10, 2003Baker Hughes IncTubular expansion apparatus and method
WO2003087533A1 *Apr 4, 2003Oct 23, 2003Baker Hughes IncApparatus and method for treating the borehole wall and expanding a screen
WO2005088067A1 *Mar 8, 2005Sep 22, 2005Campo Donald BruceDownward and upward expansion with expandable cone
WO2008151316A2 *Jun 6, 2008Dec 11, 2008Baker Hughes IncDownhole swaging system and method
Classifications
U.S. Classification166/387, 166/207
International ClassificationE21B43/10, E21B43/02
Cooperative ClassificationE21B43/105
European ClassificationE21B43/10F1