US3154145A - Methods of and apparatus for running multiple pipe strings and well packers in well packers in well bores - Google Patents

Description

Oct. 27, 1964 c. 0. BROWN 3,154,145 METHODS OF AND APPARATUS FOR RUNNING MULTIPLE PIPE STRINGS AND WELL PACKERS IN WELL BORES- Filed Nov. 25. 1959 10 Sheets-Sheet 1 C/CERO C. BROWN by 2 5: 7}'), /v 811% c. c. BROWN 5 4 METHODS OF AND APPARATUS FOR RUNNING MULTIPLE PIPE STRINGS AND WELL PACKERS IN WELL BORES Filed Nov. 23, 1959 lOSheets-Sheet 2 Oct. 27, 1964 C/CERO 6. BROWN IN V EN TOR.

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ATTORNEYS Oct. 27, 1964 c. c. BROWN 3,154,145

7 METHODS 0F AND APPARATUS FOR RUNNING MULTIPLE PIPE STRINGS AND WELL PACKERS IN WELL BORES Filed Nov. 23, 1959 '10 Sheets-Sheet 3 C/CERO C. BROWN IN V EN TOR.

A TTORNE Y5 Oct. 27, 1964 c. 0. BROWN 3,154,145

METHODS OF AND APPARATUS FOR RUNNING MULTIPLE PIPE STRINGS A D wsu. PACKERS IN wsu. BORES Filed NOV. 23, 1959 10 Sheets-Sheet 4 C ICERO C. BROWN N VEN TOR.

Oct. 27, 1964 I c. c. BROWN METHODS OF AND APPARATUS FOR RUNNING MULTIPLE PIPE STRINGS AND WELL PACKERS IN WELL BORES l0 Sheets-Sheet 5 Filed NOV. 23, 1959 4a .1 B 7 i1 17 5 5/ I C/CERO 6. BROWN INVENTOR.

qi h! 3J1 W ATTORNEYS Oct. 27, 1964 3,154,145

C. BRCWN METHODS OF AND APPARATUS FOR RUNNING MULTIPLE PIPE STRINGS AND WELL PACKERS IN WELL BORES Filed Nov. 23, 1959 1O Sheets-Sheet 6 l 72 if \M r |i i 45 60 l 62 I 1 I C/CERO 6. BROWN INVENTOR.

By g 211% Oct. 27, 1964 3,154,145

C. C. BROWN METHODS OF AND APPARATUS FOR RUNNING MULTIPLE PIPE STRINGS AND WELL PACKERS IN WELL BORES Filed Nov. 23, 1959 1O Sheets-Sheet 7 C/CERO C1 BROWN IN V EN TOR. d/mwJhAm/nh BY 2 m h. 7:}.

A 7 TOR/v5 Y5 Oct. 27, 1964 c. c. BROWN 3,

METHODS OF AND APPARATUS FOR RUNNING MULTIPLE PIPE STRINGS AND WELL PACKERS IN WELL BORES Filed Nov. 25, 1959 10 Sheets-Sheet 8 Lill INVENTOR.

C/CERO 6, BROWN A TTOR/VE Y5 3,154,145 METHODS OF AND APPARATUS FOR RUNNING MULTIPLE PIPE STRINGS AND wELL PACKERS IN wELL BORES 25, 1959 C. C. BROWN 10 Sheets-Sheet 9 Oct. 27, 1964 Filed Nov.

WLW an m mm W 1 53 Oct. 27, 1964 c. c. BROWN METHODS OF AND APPARATUS FOR RUNNING- TI PIPE STRINGS AND WELL PACKERS IN WEL 0R Filed Nov. 23, 1959 10 Sheets-Sheet 10 5/ I52 /54 M5 ,4 34/4 M 46 155 4 53 /4 34/. /42 /5'6 :2 AMMQ I [47 /3.9 'T

I /57 (1513. B9 B6 C/CEPO C. BROWN I INVENTOR. dvm BY 5, EMMA United States Patent METHODS OF AND APPARATUS FOR RUNNING MULTIPLE PIPE STRINGS AND WELL PACKERS IN WELL BORES Cicero (I. Brown, Houston, Tex, assignor to Brown Oil Tools, Inc, Houston, Tex, a corporation of Texas Filed Nov. 23, 195%, Ser. No. 354,870 14 Claims. (Cl. 166-48) This invention relates to new and useful improvements in methods of and apparatus for running multiple pipe strings and well packers in well bores.

The invention herein is an improvement upon the method and apparatus disclosed in my prior co-pending application, Serial No. 728,967, filed April 16, 1958, now Patent No. 3,098,524.

It has become the general practice to simultaneously produce well fluids from a plurality of producing zones which are traversed by a single well bore. The production from each zone must be conducted to the surface through an independent pipe or tubing string and therefore the producing zones must be separated or sealed off from each other by well packers. The running in and placement of the well packers and of the multiple tubing strings, as well as the selective removal of said packers and strings presents a considerable problem.

Various prior methods and apparatus have been employed but each have certain inherent disadvantages. In some instances, the multiple strings have been clamped or secured together and said strings having the well packers thereon are run simultaneously; this is satisfactory insofar as positioning the strings and packers within the bore but because the strings are secured together, all strings and packers must be removed simultaneously, which is a major disadvantage. It is not possible to remove one string or one packer independently of the other.

Other prior methods and apparatus, such as those illustrated in my prior Patent No. 2,903,066 and in the aforesaid co-pending application, Serial No. 728,967, disclose lowering the pipe strings into the Well bore independently of each other. Such a method has the advantage of permitting independent handling of each string but because each string must be individually landed in the upper well packer, difficulty is encountered in such landing operation where more than two tubing strings are involved. Thus, where three, four or more pipe strings are to be disposed in final position within the bore, the advantage of separate handling of the strings is overridden by the disadvantage of the difficulty in efiecting proper landing.

It is further one object of this invention to provide an improved method and apparatus for handling multiple strings and well packers which permits all of the strings and packers to be run simultaneously and yet permits independent removal of each string and each packer.

An important object is to provide an improved method of handling multiple pipe strings so that all of the strings may be lowered simultaneously, said method eliminating the requirement that all strings be clamped or otherwise secured to each other, whereby a faster running-in operation may be carried out and the other disadvantages inherent in the use of clamps are eliminated.

Another object is to provide an apparatus of the character described wherein each string above the uppermost packer may be removed independently of the other strings which is of decided advantage in the event that any one of the strings need be removed for repair or for other reasons.

Another object is to provide an apparatus of the character described wherein the uppermost packer in the well bore may be removed separately and independently from the other packers, whereby the requirement that all packers be removed simultaneously as is the case where multiple strings are clamped together is obviated.

A particular object is to provide an apparatus of the character described which includes a power-operated elevator device and a power-operated slip or spider device, with said devices being constructed to handle a plurality of pipe strings simultaneously. A still further object is to provide in an apparatus of the character described, an improved multiple string sealing device for sealing otf around a plurality of pipe strings, whereby the well is maintained under control while the multiple strings are being lowered into position within the well.

The construction designed to carry out the invention will be hereinafter described, together with other features thereof.

The invention will be more readily understood from a reading of the following specification and by reference to the accompanying drawings forming a part thereof, wherein an example of the invention is shown, and wherein:

FIGURES 1 through 10, inclusive, are schematic views illustrating the method of handling multiple strings having a plurality of spaced well packers thereon and showing the manner in which said strings and packers are run into a well bore which is traversed by a plurality of producing zones;

FIGURES 11 to 15, inclusive, are schematic views illustrating the manner of-rernoving the multiple strings and well packers from the well bore;

FIGURE 16 is a view, partly in section and partly in elevation, showing the two upper packers illustrated in the schematic views and detailing the connections between said packers;

FIGURE 17 is a view, partly in section and partly in elevation of the two lower packers shown in the schematic illustrations and illustrating the connection therebetween;

FIGURE 18 is a plan view of the supporting slip or spider device which is employed during running-in of the multiple pipe strings;

FIGURE 19 is a transverse vertical sectional view taken on the line 19-19 of FIGURE 18;

FIGURE 20 is a view, partly in section and partly in elevation, of the power-operated elevator device which is employed for handling the multiple pipe strings as they are run into or removed from the well;

FIGURE 21 is a transverse sectional view of the multiple sealing unit which is employed to seal around the multiple strings during running-in of the strings, said view illustrating the inner element of said unit being lowered into position;

FIGURE 22 is a plan view of the sealing unit with the inner element in place;

FIGURE 23 is a transverse sectional view taken on the line 2323 of FIGURE 22;

FIGURES 24 to 27, inclusive, are elevation views which illustrate the manner of manipulating the slip or spider device during the handling of the multiple strings;

FIGURE 28 is an exploded view of a modified form of the slip or spider device which may be used in lieu of the device illustrated in FIGURES 18 and 19 and which has its slip supporting bowl formed of sectional quadrants, one of which has been omitted for the sake of clarity;

FIGURE 29 is a plan view of the device shown in FIG- URE 28;

FIGURE 30 is a transverse sectional View taken on the line 30-450 of FIGURE 29; and

FIGURE 31 is an enlarged sectional detail illustrating the manner of mounting each slip member within its bowl.

General Method and Apparatus In the drawings the numeral 10 designates a well bore which traverses a plurality of well producing formations or zones, F1, F2, F3 and F4. A well casing 11 extends throughout the length of the well bore in the usual manner and has perforations 11a, 11b, 11c and 11d opposite the formations Fl through F4, respectively, whereby fluid from the formations or zones may flow into the casing. A tubing head 12 having the usual supporting seat 13 is mounted at the upper end of the casing ll above the ground level but below the derrick floor 14; the usual rotary table 15 is located above the derrick floor.

In setting up multiple production from the well bore 10, it is necessary to dispose well packers within the well casing to separate the various producing zones and to lower multiple tubing strings so that well fluids from each zone may be separately produced. The present method and apparatus has to do with the running-in and the removal from the bore of a plurality of well packers and a plurality of pipe strings. For the purpose of handling the multiple strings of pipe, 2. power elevator device, generally indicated at A and which will be more clearly here-' inafter described, is provided. In addition, a power-operated spider device, generally indicated at B, is employed and this device will be hereinafter described in further detail. The elevator device-A and the spider B are poweroperated and are arranged so that each may handle a plurality of pipe strings simultaneously. By employing power-operated devices, the elficiency of the pipe-handling operation is greatly increased and it is possible to quickly and easily lower or remove a plurality of pipe strings simultaneously without the necessity of clamping or otherwise securing said strings together.

In FIGURES l to 10, the power-operated elevator device A and the power-operated spider device B are schematically shown. The elevator device is provided with four openings A1, A2, A3 and A4 with each opening adapted to receive pipe supporting, gripping or slip elements. The spider device B is also formed with four openings B1, B2, B3 and B4 through which the multiple strings extend and which are adapted to receive pipe supporting slips. The elevator device A is, of course, adapted to be supported by the usual cable or line in which depends from the traveling block (not shown) of the drilling rig while the spider device B is arranged to be mounted on the upper end of the rotary table 15.

Referring to FIGURE 1, a first packer Pl is connected to the lower portion of the first pipe or tubing string Tl. The upper portion of the section of tubing T1 is supported within the opening A1 of the elevator device A and by means of the elevator device, packer P1 and the first section of tubing Tl are lowered within the well casing. After packer Pl has passed through the rotary table and into the upper portion of the well casing, the power-operated spider device B is placed in position on the rotary table 15. As will hereinafter appear, the spider device includes an outer body 317 which rests upon the rotary table and an inner slip bowl assembly 18. The slip bowl assembly 18 is segmental so that it may be placed in position and removed from position around the multiple pipe strings while said strings are extending into the well bore. It is, therefore, possible to selectively place the supporting slips and bowl 18 in position to support the pipe when such support is required or to remove the same while the pipe string or strings are supported by the elevator device.

When the lowermost packer Pl has moved into the upper portion of the well casing as shown in FIGURE 2, the slip bowl assembly 18 of the spider device B is placed in position with the first section of the tubing string Tl extending through the opening B1 of device B. The slips which will be hereinafter described in detail are in the opening B1 and function to support the lowermost section of tubing T1 and the lower packer Pl. it is then possible to release the elevator device A from the string T1 since the string and lower packer are supported from the spider device B.

Thereafter the second packer P2 is connected in the string Tl by means of a safety joint S1 which will be hereinafter described. The safety joint will permit a disconnection at this point during removal of the packers from the well. In addition to the connection of packer P2 with the first pipe string T1, said packer is also connected with the lowermost section of the second pipe or tubing string T2. It is noted that the lower end of string T2 is disposed below packer P2 and communicates with the area between packer P2 and the lowermost packer P1. The string T1 is rotatable within the packer P2 which will permit actuation and disconnection of the safety joint 81 when such disconnection is desired.

After the second packer P2 has been connected in the manner shown in FIGURE 2, the elevator device A is then connected through its pipe supporting elements with both tubing strings T1 and T2 in the manner shown in FIGURE 3. The slip bowl assembly 18 of the spider device B is removed andthereafter the elevator device A may lower packers P1 and P2, together with the connected sections of tubing strings T1 and T2 to the position shown in FIGURE 4.

At this time the slip bowl assembly 18 of the device B is again replaced and now tubing T1 again extends through opening Bit of the device B while tubing T2 extends through opening B2. The spider device B is thus utilized to support pipe strings T1 and T2 which have the packers P1 and P2 connected therewith. Thereafter the third packer P3 may be connected to strings T1 and T2. The string T1 extends rotatably through packer P3 and has a safety joint S2 connected therein below the packer P3. The next section of tubing T2 has a telescoping joint 19 connected therein and also may have a shear pin safety joint 20 disposed therein. The purpose of the telescoping joint is to allow setting of the packer, as will hereinafter appear, without placing undue strain on tubing string T2 while the purpose of the safety joint is to allow a disconnection at 20 in the string T2 allowing the packer P3 to be removed separately from packer P2.

After packer P3 is in position, the elevator device is reconnected not only to strings T1 and T2 but also to T3 in the manner illustrated in FIGURE 5. In such instance tubing string Tl extends through the opening A1 of the elevator device, tubing string T2 extends through opening A2 and tubing string T3 extends through opening A3. The slip bowl assembly 18 is then removed from around the pipe strings and the elevator device A is employed to lower packers P1, P2 and P3 together with their connected pipe strings further into the well. When the fourth packer P4 is to be connected in position in the pipe strings, the operation as heretofore described is repeated. That is, the slip bowl assembly 18 is placed in position around tubing strings T1, T2 and T3 and said strings are supported within openings B1, B2 and B3 of the spider device B. Packer P4 has tubing. string T1 rotatably extending therethrough and the safety joint S3 is connected in the string Tl below said packer. Telescoping connections 19a and 1%, as well as shear pin. safety joints 20a and 20b, are connected in strings T2 and T3 in the manner shown in FIGURE 6. At the time that these connections are made the spider device B is supporting all three strings and the packers P1, P2 and P3. The lower section of the fourth tubing string T4 is connected to packer P4 and has its lower end communicating with the area below said packer.

To effect lowering of the apparatus including the packer P4 into the well, the elevator device A is again reconnected will all four strings, the strings T1 through T4 being supported in the openings Al through A4, respectively, of said elevator. The slip bowl assembly 18 of the spider device B is then removed (FIGURE 7) andthe elevator device utilized to lower all four strings, together with the packers, into the well.

Because the major length of the pipe strings T1 through T4 are normally located above the uppermost packer, there is a period of time while the four pipe strings are being lowered that the well would be open. Therefore, it is desirable after the four packers have been moved into the casing that a sealing ofi around said pipes be effected. For this purpose a sealing unit C, which will be hereinafter described in detail with respect to FIGURES 21 to 23, is mounted on the upper end of the tubing head 12. This sealing unit has a plurality of sealing elements C1, C2, C3 and C4 which engage around the tubing strings T1 through T4 respectively. When in position, a sealing around all pipe strings is effected and as additiOnal stands of tubing are connected in the strings, the sealing unit C functions to maintain the upper end of the casing closed. It might be noted that the additional stands of tubing are connected to the respective strings by handling all four strings simultaneously with the elevator device A and the spider device B. As is usual practice, the pipe is supported by the spider when another stand is connected thereto; after the stand is connected, the elevator device is reconnected and utilized to effect further lowering.

After the proper or desired number of stands have been connected in the respective strings, the elevator device A is utilized to support all four strings while the sealing section of the unit C is removed. Thereafter, a pipe supporting means 21, which is schematically illustrated, is connected to the four strings TI through T4, after which the elevator device is reconnected with the upper ends of the strings in the manner shown in FIGURE 9. The pipe supporting means may be in the form of a one-piece support from which all of the pipe strings are suspended but preferably, this means is a sectional type of hanger, such as shown in the patent to Allen No. 2,794,505. Each pipe string is connected to one section of the hanger and thus may be individually landed or removed from the tubing head body.

The elevator device is utilized to lower the strings and packers into final position, the tubing supporting means 21, whether sectional or solid, seating within the bowl 1% of the tubing head 12. Thereafter, the tubing head is flanged up by the usual closure 22 and each of the tubing strings are connected to outlet lines in which a control valve 23 is disposed.

With the tubing strings in final position, the packers P1 through P4 are located to separate the production from the producing zones F1 through F4. As will be explained, the packers P1 through P4 are hydraulically actuated packers so that upon initial disposition, they are in unset position. This permits any desired circulation through the various strings and around the packers. After necessary circulation has been carried out, the packers are properly set to separate production from the various zones. This final position is illustrated in FIGURE 10. Well fluids from formation F1 are produced through string T1; production from zone F2 is through tubing string T2; production from zone F3 is through tubing string T3; and production from zone F4 is through tubing string T4.

From the foregoing it will be evident that all four strings and all four packers may be run into the well simultaneously. The provision of the power elevator device A and the power spider device B makes it possible to efiiciently handle all four strings in a manner very similar to the usual way of handling a single string. It is, of course, understood that the proper lengths of tubing sections are disposed between the packers so that when the apparatus is in its final position (FIGURE the packers are properly located to separate flow from the various producing zones.

Removal 0 Apparatus The method of removing the pipe strings and packers is illustrated in FIGURES 11 to 15. In effecting a removal of the strings and pipe, the closure 22 and the outlet lines at the surface are first removed after which the tubing supporting means 21 is removed from the tubing head; of course, if the means 21 is the sectional hanger type, each section is removed with the pipe string to which it is attached. Thereafter, a retrieving pipe 24 is connected through a suitable coupling 25 with the upper end of the first tubing string T1 in the manner shown in FIGURE 11. An elevator device E is engaged with the upper end of the retrieving pipe so that said elevator is in effect connected to the first string T1. Tubing string T1 is then rotated to disconnect the safety joint S3 which is below packer P4 and this separates the upper portion of tubing T1 from the lower portion of said tubing string. Tubing T1 may thereafter undergo a limited upward movement relative to packer P4 and such limited upward movement effects a release of the hydraulic pressure which maintained the packer P4 in set position, whereby said packer may return to an unset, nonsealing position.

Following disconnection of the safety joint S3 and unsetting of packer P4, the elevator device E is utilized to remove the tubing string T1, together with the upper packer F4 from the well. The upward pull which is effected through the upper section of string T1 will shear the safety joint connections Zita and 2% to thereby separate the upper portion of strings T2 and T3 from the lower sections thereof. Although it is possible to remove the upper sections of strings T2, T 3 and T4 simultaneously with string T1 and the packer P4, it might be desirable to remove those portions of the strings T2, T3 and T4 which are above the packer P4 independently of each other prior to removal of said string T1 and packer. Each of these strings has a threaded connection with the upper end of the packer P4 and this arrangement makes it possible to individually remove the upper portions of each string T2, T3 and T4 separately from the others; such individual removal should be carried out prior to removal of string T1 and packer P4. After such removal of strings T2, T3 and T4 is effected, then the upper portion of string T1 is utilized to bring packer P4 out of the hole, this operation being illustrated in FIG- URE 12.

After packer P4 and the upper sections of the four strings have been removed, the retrieving pipe 24 is again lowered into the bore and is reconnected to the lower half or" the safety joint S3 as shown in FIG- URE 13. String T1 is again rotated to break out the safety joint S2 which is below packer P3. Thereafter, a limited upward movement of the string T1 with respect to packer P3 releases pressure thereon and a subsequent upward pull on said packer disconnects the shear pin safety joint 2th which is in the string T2 below the packer P3. This disconnects packer P? which may then be removed from the well bore by means of the first string T1 and the retrieving pipe 24. Those portions of the strings T2 and T3 which are above packer P3 may be removed with said packer or, if desired, may be removed independently of said packer since they have threaded connection with the upper end thereof.

After packer P3 is removed, the retrieving pipe 24 is again rerun into the well bore and is reconnected with the lower half of safety joint S2. By rotating the section 24, string Til is rotated to break out the lowermost safety joint S1 below packer P2 whereby this packer is disconnected from the bottom packer Pl. Thereafter, string T1 is moved a limited distance relative to the packer to release pressure on said packer after which upward movement of the retrieving pipe and string T1 effects a removal of said packer from the well bore. If desired, that portion of the string T2 which is above packer P2 (FIG- URE 14) may be removed independently and prior to the removal of the packer.

Following removal of packer P2, the retrieving pipe 24 is again rerun in the manner shown in FIGURE 15 and its lower end is reconnected through the safety joint S1 with the remaining part of the first string T1. The lower packer is arranged to that rotation of the string T1 effects a release of the packer. Thus, by rotating the string, the packer P1 is released from its set position after which said packer may be removed from the well.

It will be evident that the apparatus is so arranged that the various portions of the multiple strings may be removed independently of each other with the result that each string can be handled separately during the removing operation. The arrangement of safety joints which are connected at the proper points in the strings makes it possible to remove the packers independently of each other. By permitting the individual handling of the strings and the independent removal of the packers during the removing operation, it is assured that all of the apparatus may be efficiently retrieved from the well bore. The invention thus provides an apparatus wherein all of the strings and packers are run into position within the well bore simultaneously, which not only speeds the running-in operation but also assures proper location of the packers in position, and yet said strings and packers may be independently handled and retrieved at any time or during the removing operation, whereby eiiicient moval is assured.

Although independent removal of the packers is preferable, there may be instances where it would be possible to remove more than one packer at a time. For example, referring to FIGURE 11, rotation of the string T1 may break out the safety joint S2 instead of safety joint S3. The joint S2 is below packer P3 and an upward pull on the first string Tl would in such case shear the safety joint 26. Thereafter, an upward pull on string Tl would effect a removal of the two uppermost packers P4 and P3. In other instances it may be possible that the lowermost safety joint Sll would break out, in which case the three packers P2, P3 and P4 might be removed simultaneously. Though not likely, there might be an instance Where, after the connection is made as in El URE 11, the initial rotation of string Tl would unset the lowermost packer P1 and a subsequent upward pull would result in an unsetting of the other three packers so that thereafter all four packers and all four strings could be removed simultaneously. At any time that removal of the four strings is being effected simultaneously, then the power-operated spider B is employed in conjunction with the power-operated elevator A in a man ner similar to that described with respect to the runningin operation. The preferable manner of removal is as illustrated in FIGURES 11 to 15 in which case the packers are removed independently of each other.

The Well Packers The particular well packers which are employed in the present apparatus are of the hydraulically-actuated type. Each packer is arranged to be lowered into the well casing in its unset position and after said packers are properly placed, a hydraulic pressure is applied thereto to move the packers into their set position; release of setting pressure is eifected by manipulation of the well pipe string. 7

In FIGURES 16 and 17 the particular packers which have been found satisfactory are shown. The packer P1 may be of the type which is more fully illustrated in my co-pending application Serial No. 69,118, filed November 14, 1960 now Patent No. 3,142,338. Said packer is a hydraulically-actuated type wherein pressure is applied to an actuating piston (not shown) within the packer to set the slips and to expand the sealing elements 26 thereof. Rotation of the string Til, which extends into the packer structure, effects an unsetting of the packer.

The packers P2, P3 and P4 are preferably of the type illustrated in my co-pending application Serial No. 728,967, filed April 16, 1958, now Patent No. 3,098,524. Each of these packers includes gripping slips 27 and a packer element 28, said slips and packer element being set by the application of internal pressure to an actuating piston element (not shown) which is located within the packer structure. Release of the hydraulic pressure in this type of packer is eifected by a longitudinal movement of the string T1 with respect to the packer, such longitudinal movement opening a port which relieves the pressure holding the packer in set position. Although 55 the packers illustrated in FIGURES 16 and 17 have been found satisfactory for use in this apparatus, other types of hydraulic or pressure-actuated packers may be employed in the assembly and there are presently other packers now available on the open market which can be used.

The particular connections between the packers and their tubing strings are shown in FIGURES 16 and 17. The tubing string Tl extends downwardly and is rotatable within passage 29 in packers P4, P3 and P2 and Within a passage 3t! in the lowermost packer P1. When that portion of the string T1 immediately above packer P1 is rotated relative to the packer, the packer is released from set position to move the packer to its unset position.

Connected in the string T1 between the uppermost packer 3 4- and the packer P3 is the safety joint S3. This safety joint is a double thread joint such as shown in my co-pending application Serial No. 743,803, filed June 23, 1958, now Patent No. 3,083,767. It is a type having both right and left-hand threads formed on the male portion of the joint. The upper section of tubing T1 is connected to the left-hand threads of said male section of safety joint S3 wh reby a right-hand rotation will disconnect the joint S3. The right-hand threads of the safety joint are subsequently used to permit connection of the retrieving pipe 24 by right-hand rotation to the lower portion of tubing Tl during removal of the apparatus.

Safety joint S2, which is of the same construction as safety joint S3, is located in the string Tl between packers P3 and P2. Similarly, safety joint S1, which is also of the same construction, is connected in string T1 between packers P2 and P1.

Tubing string T2 has the lower end of that portion above packer P4. formed with left-hand threads 31 which are adapted to engage a threaded box 32. The threaded box is formed with crisscross right and left-hand threads (similar to the threads in the safety joints S1, S2 and S3) and the left-hand threads of string T2 connect with the left-hand threads of said box 32. It is thus possible to disconnect that portion of string T2 above packer P4 by right-hand rotation and since said box 32 also includes right-hand threads, it is possible to reconnect string T2 by a right-hand rotation. Therefore, if it becomes necessary for any reason to remove and replace tubing T2 after the apparatus has been located in the well, this can be readily accomplished.

The section of tubing string T2 which extends between packers Pd and P3 is formed with the telescoping connection 19a and immediately below this telescoping section is the shear pin safety joint 20a. The telescoping section 1% is provided in order to permit some motion of pipe string T2 when packer P4 is moved to set position to thereby eleminate an excessive strain or stretch on the upper portion of string T2. String T2 is connected into the upper end of the next-below packer P3 by means of a box 32a which is similar to the box 32 in the upper end of packer P4. A continuation of string T2 extends downwardly below packer P3 and has the telescoping joint 19 as well as the shear pin safety joint 20 connected therein; the lower portion of this continuation of the string T2 has connection with the packer P2 through the double threaded box 32b. The extreme lower end of string T2 communicates with the area between packers P2 and P1.

The tubing string T3: is connected to the upper packer P4 through a box 132 which is similar to the threaded boxes 32, 32a and 32b. Between the upper packer P4 and the next below packer P3, the string T3 has the telescoping joint 1% and the shear pin safety joint 2% connected therein. Connection between pipe string T3 and the upper end of packer P3 is made by a double threaded box 1352a and the extreme lower end of string T3 communicates with the area between packers P3 and P2.

The tubing string T4 is connected in the double threaded box 232 in the upper end of packer P4 so that the portion of the string above said packer may be removed and replaced. The lower end of string T4 communicates with the area between packers P3 and P4.

As has been described in connection with the removing operation, the four packers and four strings are positioned in the well. If for any reason one of the tubing strings T2, T3 or T4 develop a leak, it is possible to remove that portion of the string above the upper packer (which is the major portion of the string) independently of the other strings. The disconnection is made at the connecting boxes 32, 132 or 232 by a right-hand rota tion. After a particular string has been removed and repaired, it may be reconnected to the right-hand threads of the double threaded box by a right-hand rotation of the particular string.

When the upper packer P4 is to be removed, the string T1 is rotated. At such time, the lower packers P3, P2 and P1 will be in set position and will tend to hold the lower portion of the string T1 stationary which will allow the uppermost safety joint S3 to break out and thereafter a slight upward movement of the upper portion of string T1 relative to upper packer P4 will release the pressure which has been holding the upper packer P4 in set position. Thereafter, a straight upward pull will shear the pins of the safety joints 20a and 20b and this will allow independent removal of the uppermost packer F4 from the well bore.

The male double-threaded portion of safety joint S3 is left in the well, being attached to that part of string T1 which has not been removed and subsequently the retrieving pipe 24 may be lowered downwardly and reconnected with this portion of said safety joint. Thereafter, the operation is repeated to disconnect safety joint S2 below the packer P3 and release packer P3, after which an upward pull will shear the pin of the safety joint 20 in the string T3. Thereafter packer P3 may be removed.

Following removal of packer P3, the retrieving pipe 24 is reconnected with safety joint S2, rotation is imparted to break out the safety joint S1 and thereafter permit release and removal of packer P2. Finally, the retrieving pipe 24 is reconnected with the male portion of safety joint S1 whereby the lower packer P1 may be released and removed.

The Pipe-Handling Devices The power-operated pipe-supporting or spider device B and the power-operated elevator device A, which are shown schematically in FIGURES 1 through 9, are illustrated in detail in FIGURES 18 to 20. These devices are constructed to handle a plurality of pipe strings simultaneously whereby said pipe strings may be lowered into or removed from the well bore at the same time.

Referring to FIGURES 18 and 19 wherein the pipesupporting or spider device B is illustrated, said device includes the outer body 17 and the slip bowl assembly generally indicated at 18. The body 17 is generally cylindrical or annular and is provided with a base flange 17a whereby the body may be supported upon the upper surface of the rotary table or other support. The body is formed with a central opening 35 which, as shown in FIGURE 19, has an inclined or tapered wall. A sectional or segmental bowl 36 is adapted to seat within the opening 35 and, as shown in FIGURE 18, the bowl is constructed in four sections or segments and the abutting or adjacent faces of the sections are formed of complementary recesses which co-act with each other when the bowl is in place to form the openings B1, B2, B3 and B4 through which the pipe strings are adapted to extend. The openings or bores B1 through B4 are actually circumferentially spaced around the bowl rather than disposed in transverse alignment as schematically illustrated in FIG- URES 2 to 9. Each bowl section has an upper flange which overlies the body 17 and is removably secured thereto by bolts 37. With the sectional construction of the bowl, the sections may be removed from and returned 10 to position in the body 17 while the pipe strings are extending through the body.

Each of the bores B1 through B4 has a plurality of recesses 38 which are spaced equi-distant around the circumference of the bore; each recess has an inclined or tapered rear wall 38a. A pipe gripping element or slip 39 is movable vertically within each recess 38 and is retained and guided therein by guide grooves 38b. The number of slips within each bore or opening is variable and as illustrated three slip elements are shown. Each slip element is slidable axially of the bore or opening within each recess, and it will be evident that as the slips move downwardly along the tapered rear surface 3&1 of the recess, the gripping teeth on the inner surface of each gripping element will engage the pipe extending through the bore. When the slip members are moved upwardly with respect to the bowl, said slips are positively moved radially outwardly by reason of the co-action of the tapered rear wall 38a and guide grooves 38b with said slips so that their gripping teeth disengage the pipe. Each slip element is formed with an extension 46 which projects upwardly therefrom.

For controlling the vertical movement of the said slips 39 to control the engagement and disengagement thereof with the pipe, a lifting member 41 is provided. The lifting member is generally in the form of a circular plate and overlies the upper surface of the bowl 3a in spaced relationship thereto. The plate is detachably secured to the upper end of a number of axial guide stems 141, each of which has its lower portion slidable within a central bore in the bowl 1'7; the connection between the plate and each stem is made by threading a nut 141a onto the upper end of the stem. Aligned with each bore B1 through 134 is an opening 42 which is formed in the lifting plate 41. Each opening 42 has radially extending recesses 43 (FIG- URE 18) which are spaced equidistant around the opening and which communicate therewith. Each recess receives the extension 40 of one of the slip elements 39, said extension projecting upwardly above the upper surface of the lifting plate; to suspend each slip element from the plate, a transverse pin 44 is mounted within a transverse bore formed within the upper end of the extension 4% and the extremities of the pin overlie and engage the upper surface of the plate. With this arrangement it is evident that as the lifting plate 41 is raised, the slip elements 39 are lifted with respect to the bowl; by reason of the radial recesses 43 within which the extensions of the slip elements are mounted, the slip members may undergo radial as well asvertical movement, whereby the slip elements are retracted from pipe-engaging position. When the lifting plate 41 is lowered, the underside of said plate engages the upper surfaces of the slips to move the same downwardly within the inclined portion 38 of the bowl, whereby each set of slips within its respective bore is moved into pipe-engaging position.

For actuating the lifting plate 41 to raise or lower the slip elements, diametrically opposed support arms 45 extend radially from the periphery of the plate. Each arm has its outer end removably secured to the upper end of a piston rod 46 by nuts 46a, and the lower end of said rod is secured to a piston 47 which is adapted to reciprocate within a power cylinder 48. Each power cylinder is mounted on a suitable bracket 49 secured to the side of the housing 17, and fluid pressure lines 50 and 51 are connected to each end of the cylinder, said lines extending to a point remote from the device B; by controlling the application of pressure through lines 50 and 51, the piston 47 of each cylinder may be moved within its cylinder to effect either a raising or lowering of the lifting plate 41, whereby the position of the slip elements is controlled. The particular power fluid which may be air, gas or liquid which operates the pistons 47 is subject to variation. The use of the power pistons permits control of the slip members from a point remote from the device B.

The power-operated elevator device A is illustrated in FIGURE 20. This device is preferably constructed in accordance with the device shown in my co-pending application Serial No. 832,283, filed August 7, 1959 and now abandoned and of which co-pending application Serial No. 208,178, filed July 2, 1962, is a continuationin-part. The construction of the device A is substantially the same as the spider device except that its bowl 36a is not sectional or segmental but is substantially annular. Also, the body 17b of the elevator device does not require a base flange but instead is provided with supporting lugs 52 which are disposed on opposite sides of the body 17b. A suitable cable or line is connected to the supporting lugs 52 to suspend the elevator device within the derrick in the usual manner.

Other than the foregoing diiferences, the elevator device A is constructed substantially the same as the spider device and includes gripping or slip elements 39a which are suspended from a lifting plate 41a. The lifting plate is actuated by pistons 47a which have their piston rods 146 connected to lift anns 45a extending outwardly from lifting plate 41a. Since the multiple pipe strings are inserted within the respective openings A1 through A4 of the elevator device, it is not necessary that the bowl 36a be split, as is the case with the spider device. In the case of the spider device, it is desirable that the bowl be split so that the slip members and bowl may be removed from around the pipe strings while said pipe strings extend through the bores B1 through B4 of said spider device B.

The manner of using the power-operated spider device and the power-operated elevator device in running the multiple strings into the well bore is illustrated in detail in FIGURES 24 to 27. In these figures, for the sake of clarity, pipe strings T2 and T4 have been omitted. Referring to FIGURE 24, the spider device B is shown in position on the rotary table and in this view the lifting plate 41 is shown in raised position, whereby the slip elements 39 are in nonengaging position with the pipe strings T1 and T3 which are extending through the openings B1 and B3 of the bowl assembly 18. At this time the slips 39a of the elevator device A are in engaged position gripping the pipe strings T1 and T3, the lifting plate 41a of the elevator device being in its lowered position. The cable or line 16 is secured to the elevator device and is suspended from the usual traveling block (not shown) of the well derrick.

With the parts in the position of FIGURE 24, the elevator device A is supporting the pipe strings and may be utilized to lower the strings T1 and T3 downwardly into the well bore. As the strings are lowered so that the upper end of the uppermost stands is adjacent the spider device, it is desirable to support the pipe strings by the spider device so that the elevator A may be disengaged from the pipe and removed. Thereafter, additional stands of pipe are to be connected to the pipe strings T1 and T3.

When the upper ends of the strings T1 and T3 reach the position shown in dotted lines in FIGURE 24, the pistons 47 of the spider device B are actuated to lower the lifting plate 41 and cause the slips 39 of said spider device to engage the pipe strings T1 and T3. When so engaged, the spider device functions to support said strings and the elevator device is then actuated to release its slips and the elevator is then pulled upwardly away from the upper ends of the supported strings T1 and T3. If another stand of pipe is to be connected in each of the strings T1 and T3, such stand is then connected, after which the elevator device is re-engaged with the added stands, the spider device is actuated to release the slips from engagement with the pipe and the elevator device is utilized to again lower the strings downwardly. When the point at which a packer is to be connected to the strings is reached, it is necessary that the bowl 36 of the spider device be removed in order that the packer may 12 be moved downwardly into the well bore and FIGURES 25 to 27 illustrate the operation to permit connection of the packer and lowering thereof into the well bore.

Referring to FIGURE 25, the pipe strings T1 and T3 are supported by the spider device B with the slips 39 in pipe-engaging position. At this time, the nuts 141a are removed from the guide stems 141 to disconnect the lifting plate 41 from said stems; also, the pins 44 of the various slip members are removed from the transverse bores in the respective extensions 40 of said slip elements so that the slips are, in effect, disconnected from their suspended position on the lifting plate. The nuts 46a, which connect each piston rod 46 to the lifting plate 41, are also removed whereby the lifting plate 41 is completely disconnected from the rest of the assembly.

When this disconnection of the lifting plate has been accomplished, a cable or line 116 is preferably secured to the outer ends of the supporting arms 45 in the manner shown in FIGURE 25, and the line 116 is employed to raise the lifting plate 41 and completely remove it from the assembly; if desired, the plate 41 may be removed by hand. At this time the gripping slips or elements 39 are supporting the pipe strings T1 and T3.

After the lifting plate 41 has been removed, one of the packers indicated at P in FIGURE 26 is connected in the strings T1 and T3. After the packer is in connected position, the elevator device A is re-engaged with the upper ends of the strings T1 and T3 as shown in FIGURE 26. Now that the strings are supported by the elevator device, it is possible to remove the gripping elements 39 and the split bowl 36 of the device B. When the split bowl and slips are removed from device B, the full opening of the bore 35 in the body 17 of device B is available to permit passage of the packer P and the elevator device A is employed to lower the strings T1, T3 and the packer downwardly through the device B and into the well bore.

After the packer has passed through the device B and the upper ends of the pipe strings T1 and T3 have moved into close proximity with the device B, the split bowl 336 and the slip members 39 are replaced within the housing or body 17 of device B (FIGURE 27) Then the line 116 is utilized to return the lifting plate 41 back into position on the upper end of the device B. As the lifting plate 41 moves back into position, its arms 45 are reconnected with the operating piston rods 46, each pin 44 is replaced in the extension 41) of each slip element 39 and nuts 141a are threaded onto the guide stems, whereby the device B is completely reassembled in the manner shown in FIGURE 24. Thereafter, the operation is repeated in the manner heretofore described, whereby the pipe strings are alternately supported by the spider device and by the elevator device as the various stands and packers are run into the well. The arrangement of the spider device with the split bowl 36 makes it possible to remove the split bowl assembly from the device B in order to permit the passage of the packer through device B.

Since both the devices A and B are power-operated, their slip members may be controlled from a remote point. For example, the valves shown in a single V having controls V1 and V2 (FIGURE 24) which control the application of fluid pressure to said devices may be located at some convenient place on the derrick floor, preferably adjacent the position of the driller. The devices A and B are adapted to handle a plurality of strings simultaneously, and thus the running-in time for placing all of the strings and all of the packers in position within the well bore is greatly reduced. It is noted that by handling the separate multiple strings with the single elevator unit and the unitary spider device, it is not necessary that the various strings be clamped together as they are lowered into the hole. This not only saves considerable time during the running-in operation, but also has the added advantage of subsequently permitting independent and individual removal of the various sections of the strings and of the well packers.

The Sealing Unit Normally the multiple well packers are located at a considerable distance below the surface of the well and, therefore, after the last or uppermost packer has been started into the well bore, there is a considerable length of pipe still to be lowered into the well; as a matter of fact this length of pipe usually constitutes the major portion thereof. This distance may vary from 2,000 or 3,000 to as much as 8,000 or 10,000 feet. Since the packers are lowered into the bore in nonsealing position, it is evident that the well is substantially open during the lowering of the strings into the bore. It has been found desirable to provide a sealing unit for sealing off around the multiple strings during the lowering of the strings into the well after the uppermost packer has already been positioned in the well and one type of sealing unit which will effectively seal off the well bore around the multiple strings is illustrated in FIGURES 21 to 23.

The sealing unit includes an annular body or housing 60 having a base flange 61 which is adapted to be secured to the upper end of the tubing head 12 by suitable bolts 62. The body or housing includes an axial bore 63 which may be bevelled inwardly at its lower end. An enlarged counterbore 64 at the upper end of the body permits the provision of an annular inclined seat 65 within the bore of the body. A locking collar 66 is adapted to be threaded, preferably by acme type threads 67 onto the upper end of the body and this collar projects upwardly therefrom. The collar has an inwardly directed flange 68 on the upper portion and the underside of the flange forms an internal annular shoulder 69 within said collar. A plurality of vertical slots or recesses 70, which are spaced at circumferential points around the collar, are formed in the inner periphery of the flange 68.

A sealing assembly generally indicated at D is adapted to mount within the housing or body 60. The sealing assembly includes an upper block 71 which is generally circular in shape and a complementary lower block 72; the blocks are secured together by suitable bolts 73 (FIG- URE 21). The block 71 has radially extending lugs 74 which are of a shape to engage and move through the recesses 70 provided in the collar 66. An eye 75 extends upwardly from block 71 whereby a cable or line 76 may be employed to lower the sealing assembly D into position. Molded to the lower end of the lower block 72 is a plurality of sealing sleeves 77, one of these sleeves being provided for each pipe string. As shown in FIGURE 23, the sealing sleeves each have a bore 78 which is adapted to snugly engage the pipe string (shown in dotted lines) which extends therethrough. The outer surface of each sealing sleeve is tapered or reduced as indicated at 79 whereby when the sleeve is in engagement with the pipe, any pressure exteriorly of the sleeve will urge the same into tighter sealing engagement with the pipe.

In using the sealing unit, the body or housing 60 is mounted on the tubing head 12 and after the uppermost packer is in position within the well, the multiple strings are extending upwardly therefrom and are supported by the spider device B. At this time the sealing assembly D is engaged over the upper ends ofthe pipe strings and each pipe string is passed through one of the sealing sleeves 77. The pipe strings are then supported by the elevator device A and the bowl assembly 13 of the device B is removed; then by means of the line 76 the sealing assembly D is lowered downwardly, sliding along the pipes until it moves into position within the body or housing 60. As the sealing assembly enters the body or housing, the radially extending lugs 74 move downwardly through the recesses 70 in the collar 66; by the time the bevelled surface 72a of the block 72 engages seat 65, the lugs 74 have moved below the level of the annular shoulder 62 formed within the collar. Thereafter, the locking collar 66 is rotated to move the recesses 70 out of alignment with the lugs 74 of the assembly (as indicated in dotted lines in FIGURE 22), after which the fast acting relatively coarse threads 67 function as a cam to force the assembly D into tight sealing position on the seat 65. Thus, the sealing assembly is locked against upward displacement within the body 60. The sealing sleeves 77 are in engagement with the exterior surfaces of the pipe strings and seal off therearound and with the sealing assembly in place, the upper end of the Well bore is closed (FIGURE 8). Whereby the pipe string may subsequently be lowered into the well without danger of the well getting out of control during the running-in op eration.

As previously explained, after all lengths of the pipe string have been run, the sealing assembly D is removed by merely first rotating the locking collar 66 to realign the lugs 74 with recesses 70 and then pulling the assembly upwardly over the upper ends of the pipe strings. Thereafter, the supporting block 21 which supports all pipe strings from the tubing head (FIGURES 9 and 10) is placed in position and the final well hookup is completed.

Operation From the foregoing it is believed that the operation of the apparatus and the practice of the method is obvious. By employing the power-operated spider device which handles multiple strings and using a power-operated elevator device also adapted to handle multiple strings, it is possible to lower a plurality of strings and a plurality of packers within a well simultaneously. Since the spider device and elevator device are alternately used to support and lower the pipe strings, it is not necessary that the pipe strings be clamped or otherwise secured together. This results in lowering all of the packers and all of the strings into position within the well bore more efficiently and in considerably less time than would be the case if the various strings were handled independently.

FIGURES 1 to 10, inclusive, illustrate the various steps of the method whereby the packers and strings are moved into final position. As the first packer P1 is lowered by means of the elevator device A (FIGURE 1), this packer is moved into the well casing 11. Each time that another stand is added, the spider device B is placed in position at the top of the well and supports that part of the string which is within the well while an additional stand is added. Also, when it is desired to connect the next packer, the device B supports the pipe which is suspended in the well. After the second packer P2 (FIGURE 2) is connected in the strings, the elevator device is again reconnected and the spider device is removed. This permits packer P2 to be lowered into the casing as shown in FIGURE 3. The operations are repeated with packer P3 and packer P4 in the manner shown in FIGURES 4 to 7.

After all packers are in the well casing, the sealing unit C is then positioned so that the sealing sleeves 77 of said unit seal 01f around each of the pipe strings. Thereafter the desired number of stands are run by utilizing the pipe supporting or spider device B and the elevator device A in the manner hereinbefore described. After all strings are in the well and the packers are properly positioned, the upper end of the well is closed as shown in FIGURE 10, the packers are set and production through individual strings is carried out.

Although it is desirable that the pipe strings and packers be run simultaneously, it is preferable that the strings and packers be capable of removal from the well bore individually or independently of each other. The present method and appartus make it possible to independently remove the various strings and to independently remove the packers. As previously described, the safety joints S3, S2 and S3 are provided between the packers. These safety joints are all connected in the first string T1 and are capable of disconnection by a right-hand rotation of the upper portion of string T I. In addition, the safety joints 20 and 20a, which are shear pin types of joints, are connected between packers P2 and P3 and packers P3 l and P4, respectively. Shear pin safety joint Ztlb is also connected between packers P3 and P4.

The removal of the apparatus is illustrated in FIG- URES 11 to 15. When removal is to be effected, a retrieving string 24 is connected to the upper end of the tubing string T1. If desired, strings T2, T3 and T4 above the packer P4 may be individually removed prior to the time that packer P4 is removed. To remove packer P4, the upper portion of string T1 is rotated to disconnect the safety joint S3. Thereafter, an upward pull will shear the safety joints 20a and 29b and allow removal of the uppermost packer P4 as shown in FIGURE 12.

After packer P4 is removed, the retrieving string 24 is rerun and reconnected with safety joint S3. The operation is then repeated to break out safety joint S2 and to shear the safety joint 29 after which packer P3 may be removed. Thereafter, the retrieving pipe 24 is again lowered, is reconnected with safety joint S2 (FIGURE 14) and safety joint S1 is disconnected. This allows removal of packer P2. Finally the retrieving pipe 24 is again lowered and is connected with safety joint S1 to finally retrieve the lowermost packer P1.

The method and apparatus permits the running of any number of strings and any number of packers in a minimum amount of time. All of the advantages of running all of the strings and packers simultaneously and without requiring that the strings be connected together are obtained and yet when the equipment is to be removed from the well, the various portions of the strings may be removed independently and each of the packers may be removed independently. As previously noted, there may be instances where more than one packer can be retrieved at a time. For instance, referring to FIGURE 11, if the safety joint S2 should break out upon initial rotation of the upper portion of string T1, then a subsequent upward pull on the string T1 would shear the safety joint 20 and would allow packers P4 and P3 to be retrieved simultaneously. However, in most instances, it is preferable to release the various packers one at a time and to retrieve them independently of each other. In all cases the operator has a choice as to whether or not he wishes to retrieve the portions of the strings individually or to remove them simultaneously with one of the packers.

Modification of the Spider Device The spider device of FIGURES 18 and 19 includes the lifting plate which is in the form of a solid circular member which must be removed by pulling the plate upwardly along the pipe strings. In order to eliminate the necessity of removing the solid lifting plate 41 by moving it upwardly over the ends of the pipe strings, as heretofore described, it is possible to construct the lifting plate in sections whereby said plate may be readily disassembled and merely removed by lateral movement in a radial direction and in FIGURES 28 to 30 such a construction, which includes a segmental lifting member, is illustrated.

Referring to FIGURE 28, which is an exploded view of this modification, the device includes an outer housing or body 117, which is similar in construction to the body 17. The sectional slip bowl 136 is of substantially the same construction as the slip bowl 36 of the previous form. Gripping'slips 139, of substantially the same construction as the slips 39, are provided and said slips have upward extensions 140 which receive the suspending pins 144a.

In place of the solid lifting plate 41, a sectional or segmental lifting plate 241 is provided. This plate includes four quadrants or sections Q which, when fitted together, form a substantially circular lifting member. Each quadrant has a upstanding arcuate extension and when the quadrants are fitted together, these arcuate sections form an annular sleeve member 142 having a tapered upper end 143. A retaining ring 144 is adapted to encircle this tapered portion and functions to hold the four quadrants together so that the sleeve 142 is in close engagement with a vertical guide stem 341, the lower portion of which is movable within a central bore in the bowl 136. A nut 341a threaded onto the upper end of the guide stem holds the retaining ring 144 in position on the sleeve 14? and thereby maintains the quadrants in connected position. Additionally, a clamp ring 146 encircles the quadrants and also functions to maintain said quadrants in position.

Secured to the upper end of the stem 341 is an extension 149 which has its exterior recessed at 151 An actuating lever 151, which is pivoted at 152 to a supporting post 153, has one end confined within the recess 15%. Its other end is connected by a U-clamp 154 with the piston rod 46 of an operating piston 47 which is movable within the cylinder 48. Movement of each quadrant of the lifting plate 241 is guided by a suitable guide pin 155 which extends upwardly from the bowl 136. The slips 139 are suspended from openings 155 formed in the lifting member and are guided within recesses 157 which are formed in the wall of each bore of the bowl 136 (FIGURE 31).

In the operation of this modification, the cylinder 48 is supplied with pressure to move the piston 47 and swing the operating arm 151. Through its connection with the guide stern 341, to which the lifting member 241, formed by the quadrants Q is secured, said lifting member is raised and lowered to raise and lower the slips. When it is desired to remove the lifting member from around the pipe strings extending therethrough, it is only necessary to first disconnect the operating lever 151 and then remove the retaining nut 341a and retaining ring 144 which encircles the extensions at the center of the plate. The peripheral clamp ring 1% is then removed after which the four quadrants may be moved laterally or radially outwardly from around the pipe strings. The slips and bowl remain in position in the manner shown in FIGURE 25 whereby the pipe strings are supported but the lifting plate has been removed. The use of the quadrant-type lifting plate permits the easy removal and replacement of said quadrants whereby the lifting member formed thereby may be placed in posi tion or removed as conditions require.

The foregoing disclosure and description of the invention is illustrative and explanatory thereof and various changes in the size, shape and materials, as well as in the details of the illustrated construction, may be made within the scope of the appended claims without departing from the spirit of the invention.

What I claim is:

l. A well apparatus including, a plurality of well packers, a plurality of pipe strings having connection with said packers, a spider device adapted to be mounted at the surface of the well and having means for temporarily supporting said pipe strings within the well bore, poweroperated means forming part of the spider device for controlling operation thereof, an elevator device having means for suspending all of said pipe strings, poweroperated means forming part of the elevator device for controlling operation of said elevator device, whereby said elevator and said spider devices may be utilized to simultaneously lower said strings and packers into a well bore, and control means located remotely from the poweroperated means of both spider device and elevator device for controlling the actuation thereof from a remote location.

2. A well apparatus as set forth in claim 1, wherein each packer includes setting means actuated by a fluid pressure for setting said packer, and means conducting fluid pressure from one of the pipe strings to said setting means to set each packer after all packers and strings are properly located Within the well bore.

3. A well apparatus including, a lower packer, an intermediate packer and an upper packer, a first tubing string extending from the surface downwardly through all packers and having its lower end in communication with the area below the lower packer, a second tubing string extending downwardly from the surface and having a releasable connection with the upper packer, said second string having an extension which extends downwardly from the upper packer and through the intermediate packer with its lower end communicating with the area between the intermediate and lower packers, a third tubing string extending downwardly from the surface and having releasable connection with the upper packer, said third tubing string having a conductor means which communicates the area between the upper and intermediate packers with the third tubing string, said strings and said packers being lowerable together as a unitary apparatus into final position within the well bore, means for actuating the releasable connection between the second tubing string and the upper packer by manipulation of the second string for releasing the second string from the upper packer to permit independent removal of said second string, and means for actuating the releasable connection between the third tubing string and said upper packer by manipulation of the third tubing string for releasing the third string from the upper packer to permit independent removal of said third tubing string.

4. A well apparatus as set forth in claim 3, together with a disconnectible safety joint mounted in the first tubing string at a point between the upper and intermediate packers, a second disconnectible safety joint in said first tubing string at a point between the intermediate and lower packers, a disconnectible safety joint mounted in the extension portion of the second tubing string between the upper and intermediate packers, and means actuated by manipulation of the first tubing string for disconnecting the first safety joint in said first string and also for disconnecting the safety joint in the extension portion of the second string whereby that part of the first tubing string above the upper packer as well as the upper packer may be removed from the well bore while leaving the intermediate and lower packers in said well bore.

5. A Well apparatus as set forth in claim 4, together with a retrieving pipe string which may be run into the well bore after the upper packer is removed, means operated by manipulation of the retrieving string for first connecting the retrieving string to the lower portion of the first string, and thereafter disconnecting the second safety joint in said first string which is below the intermediate packer, whereby the intermediate packer may be removed from the well bore while leaving the lower packer in position therein.

6. A well apparatus as set forth in claim 5, wherein the retrieving string is subsequently lowered into the well bore after the upper and intermediate packers have been removed, and means actuated by manipulation of said retrieving string for connecting said retrieving string to the remaining portion of the first tubing string whereby removal of the lower packer may be effected.

7. The method of lowering and removing from a well bore a well apparatus, which comprises a plurality of well packers and a plurality of tubing strings, said method including, lowering tubing strings into the well bore, mounting the well packers in spaced positions on said tubing strings as said strings are being lowered into the well bore, thereafter handling the tubing strings and packers as a unitary assembly to simultaneously lower all strings and packers to final position within the well bore, subsequently disconnecting the uppermost packer from the plurality of tubing strings at a point below said upper packer, thereafter removing those portions of the tubing strings above the upper packer as well as said upper packer from the well bore, thereafter disconnecting the next below packer from the strings at a portion below said last-named packer, and removing said last-named packer and any portions of the tubing strings thereabove from the well bore, and repeating the disconnecting and removing steps to effect removal from the well bore of all of the well packers and strings.

8. The method of handling a well apparatus which comprises at least a trio of spaced well packers and at least a trio of tubing strings, said method including, mounting a lower well packer on a first tubing string, suspending said first string from an elevator device and lowering said string and lower packer into the bore a predetermined distance, supporting said string in a spider device at the well surface and disconnecting the elevator device from engagement with the string, mounting an intermediate packer on said first string, connecting a second tubing string with said intermediate packer, suspending both strings from said elevator device, removing the spider device from engagement with the first string, thereafter simultaneously lowering both tubing strings having the packers thereon a further predetermined distance within the bore, then supporting both tubing strings from the spider device, disconnecting the elevator device from engagement with said strings, mounting an upper packer on the first and second strings, connecting a third tubing string with said upper packer, suspending all three tubing strings from said elevator device, removing the spider device from engagement with the first and second strings, and thereafter simultaneously lowering all three tubing strings having the well packers thereon into final position within the well bore.

9. The method as set forth in claim 8, together with the step of sealing the area between the well bore and the three tubing strings after the upper packer has been moved into the well bore and while the lowering of said tubing strings is being accomplished.

10. The method as set forth in claim 9, with the additional steps of removing the seal around said tubing strings after the strings and packers are in final position, thereafter mounting well head control equipment on the upper end of the well to close the same, setting the packers into sealing engagement with the well bore to separate production zones, and thereafter producing fluids from each zone through one of the tubing strings.

11. The method as set forth in claim 10, together with the additional steps of, disconnecting the upper packer from the first and second strings at a point below the upper packer, thereafter removing those portions of the first and second strings above said upper packer and the third string as well as the upper well packer from the well bore, subsequently disconnecting the intermediate packer from the first string at a point below the intermediate packer, removing that portion of the first string above the intermediate packer and the remaining portion of the second string as well as said intermediate packer from the well bore, and finally retrieving the lower packer and remaining part of the first tubing string from said well bore.

12. The method as set forth in claim 11, wherein those portions of the first and second strings above the upper packer are independently removed prior to removal of the upper packer, and also wherein the remaining portion of the second string is removed prior to removal of the intermediate packer.

13. An apparatus for lowering a plurality of well pipe strings into a well bore including, an elevator device attached to a supporting cable in the well derrick and having means for suspending a plurality of well pipe strings therefrom, remotely located means for controlling the suspending means whereby the pipe strings may be selectively engaged and disengaged by said means, a spider device at the surface of the well bore and comprising an outer housing and an inner sectional bowl assembly, said bowl assembly having a plurality of openings therein through which the plurality of pipe strings may extend and each opening having pipe-engaging elements therein for engaging and supporting said strings, and remotely lo cated means for controlling the position of the pipe-engaging elements to selectively engage and disengage the elements from their respective pipe strings, said elevator device and said spider device being actuated to alternately support all of the pipe strings whereby said strings may be lowered into the well bore simultaneously.

14. An apparatus as set forth in claim 13, together with means for removably mounting the sectional bowl assembly Within the housing of the spider device, whereby said assembly may be removed from its position surrounding the pipe strings while said pipes are extending through the spider housing and are suspended from the elevator device.

Penick et a1 Oct. 13, R942 Rhoades Aug. 5, 1952 20 Wilson Aug. 19, Martin Oct. 7, Ilfrey et a1. May 7, Taylor Oct. 22, Palmer -2 Nov. 26, Richardson et a1 Mar. 4, Meyer Dec. 9, Moseley June 30, Brown Sept. 1, Brown Sept. 8, Brown Mar. 12, Brown July 23,

Claims (1)

1. A WELL APPARATUS INCLUDING, A PLURALITY OF WELL PACKERS, A PLURALITY OF PIPE STRINGS HAVING CONNECTION WITH SAID PACKERS, A SPIDER DEVICE ADAPTED TO BE MOUNTED AT THE SURFACE OF THE WELL AND HAVING MEANS FOR TEMPORARILY SUPPORTING SAID PIPE STRINGS WITHIN THE WELL BORE, POWEROPERATED MEANS FORMING PART OF THE SPIDER DEVICE FOR OPERATED MEANS FORMING PART OF THE SPIDER DEVICE FOR CONTROLLING OPERATION THEREOF, AN ELEVATOR DEVICE HAVING MEANS FOR SUSPENDING ALL OF SAID PIPE STRINGS, POWEROPERATED MEANS FORMING PART OF THE ELEVATOR DEVICE FOR CONTROLLING OPERATION OF SAID ELEVATOR DEVICE, WHEREBY SAID ELEVATOR AND SAID SPIDER DEVICES MAY BE UTILIZED TO SIMULTANEOUSLY LOWER SAID STRINGS AND PACKERS INTO A WELL BORE, AND CONTROL MEANS LOCATED REMOTELY FROM THE POWEROPERATED MEANS OF BOTH SPIDER DEVICE AND ELEVATOR DEVICE FOR CONTROLLING THE ACTUATION THEREOF FROM A REMOTE LOCATION.

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