US2788857A - Packer and tubing string combination - Google Patents

Description

A. K. KLINE El AL PACKER AND TUBING STRING- COMBINATION Original Filed Aug. 8, 1950 April 16, 1957 2 Sheets-Sheet 1 ALBERT L. Elm/5, MART/1V B. CON/2A0,

INVENTORS.

Ante/vex? April 16, 1957 A. K. KLINE ETAL PACKER AND TUBING STRING COMBINATION Original Filed Aug. 8, 1950 2 Sheets-Sheet 2 INVENTORS.

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United States Patent PACKER AND TUBING STRING COMBINATION Albert K. Kline, Tulsa, Okla, and Martin B. Conrad, Downey, Calif., assignors to Baker Oil Tools, Inc., Los Angeles, Calif., a corporation of California Original application August 8, 1950, Serial No. 178,212,

now Patent No. 2,713,907, dated July 26, 1955. Divided and this application August 24, 1953, Serial No. 376,084

8 Claims. (Cl. 166-414) The present invention relates to subsurface well tools, and more particularly to well packer and tubing apparatus adapted to be set and located in well bores.

This application is a division of our application for Wire Line Packer and Tubing String Combination, Serial No. 178,212, filed August 8, 1950, now Patent No. 2,713,907.

An object of the invention is to provide an improved leakproof connection between a well packer and a tubing string.

A further object of the invention is to provide a hydraulically balanced adapter or connection between a tubing string and a well packer; so that fluid pressure within the equipment cannot tend to shift the tubing string relative to the packer.

Another object of the invention is to provide a leakproof connection for conducting fluid between a well packer and a tubing string, in which the tubing string is placed easily into proper association with the packer that has been set previously in a well bore, the tubing string also being easily released from the packer for withdrawal from the well bore.

This invention possesses many other advantages, and has other objects which may be made more clearly apparent from a consideration of a form in which it may be embodied. This form is shown in the drawings accompanying and forming part of the present specification. It will now be described in detail, for the purpose of illustrating the general principles of the invention; but it is to be understood that such detailed description is not to be taken in a limiting sense, since the scope of the invention. is best defined by the appended claims.

Referring to the drawings:

Figures 1 and 1a together constitute a longitudinal section through a well apparatus disposed in an open well bore, Fig. la constituting a lower continuation of Fig. 1;

Fig. 2 is a cross-section taken along the line 2-2 on Fig. 1;

Fig. 3 is a cross-section taken along the line 3-3 on Fig. 1a;

Fig. 4 is a view similar to Fig. 1a, illustrating the well packer set in the well bore and cementitious material being dumped upon it.

Fig. 5 is a view similar to Figs. 1a and 4, disclosing a tubing string in leakproof relation to the set well packer; I

Fig. 6 is a crosssection taken along the line 6-6 on Fig. 5; V

Fig. 7 is a cross-section taken along the line 7-7 on Fig.5.

As disclosed in the drawings, the apparatus includes a well packer A adapted to be expanded to a substantial extent into leakproof engagement with the well of an open well bore B. After having been set in the well bore by means of a setting tool C, the latter is released from the packer and cementitious material D, contained in. the

2,788,857 Patented Apr. 16, 1957 dump bailer portion E, of the setting tool dumped upon and around the set packer.

The cementitious material D sets and hardens in the well bore B to form a supplemental plug therein, which can also anchor the packer A in the well bore and hold its main body portion 10 centered with respect to the well bore, in order that the subsequent leakproof association of a tubing string F with the packer can be facilitated. The well packer has a passage 11 therethrough which will communicate with the tubing string, to allow fluid to pass in both directions between the well bore B below the well packer A and the interior of the tubing string.

The well packer and setting tool combination are preferably run in the well bore on a wire line running-in string G, and after the packer has been set and the cementitious material D dumped thereupon, the setting tool C may be retrieved to the top of the well bore through elevation of the wire line.

The packer A disclosed in the drawings includes the tubular main body portion 10, which has a lower abutment and guide 12 threadedly secured on its lower end. A packing element or structure 13 surrounds the body, with its lower end resting upon the guide 12, and with its upper end supporting an upper abutment 14 slidably mounted upon the packer body 10. The packing element or structure 13 preferably includes a plurality of packing sleeves 15 which are separated by an intervening washer or disc 16. Moreover, to limit the extent of outward expansion of the packing element, a tubular stop sleeve 17 is disposed therewithin, which is slidable relative to the tubular body 10. Originally, this stop sleeve had a substantially shorter length than the distance between the upper and lower abutments 14, 12.

The packing element 13 is expanded outwardly into engagement with the wall of the confining well bore B by moving the abutments 14, 12 toward one another, thereby foreshortening the packing sleeves 15 and cansing the latter to bulge outwardly toward the formation. As explained hereinafter, a downward force is imposed upon the upper abutment 14 and an upward force on the tubular body 10 for the purpose of shifting the abutments toward one another. The extent of approach of the abutments is limited by their engagement with the upper and lower ends of the tubular stop sleeve 17, which determines the maximum amount of outward expansion of the rubber packing sleeves 15 into engagement with the bore hole.

The abutments 12, 14 are precluded from moving away from each other, thereby possibly allowing retraction of the packing sleeves 15, by a one-way lock device of any suitable form. As disclosed, this lock device is mounted within the upper abutment 14, consisting of a split sleeve 18 adapted to frictionally engage the exterior of the packer body 10. This sleeve has outer downwardly inclined surfaces 19 engageable with companion inner surfaces 20 in the upper abutment 14. It is apparent that downward movement of the upper abutment 14 along the body 10, or relative upward movement of the tubular body within the upper abutment, is permitted by the sleeve 18. However, movement of these parts in a reverse direc tion is precluded, since it effectively shifts the lock sleeve or ring 18 in a downward direction with respect to the upper abutment 14 and causes the coengaging cam faces 19, 20 to wedge the sleeve more firmly into engagement with the packet body 10.

The packing element or structure 13 has a compara tively long over-all initial length; so as to provide sufficient packing material for outward expansion to a substantial extent into engagement with the wall of the confining enclosure or well bore 3. The making of this element as a single rubber sleeve, for example, might tend to cause its buckling during outward expansion to large extent, and an improper and inadequate pack-off against the wall of the well bore might result, Such single packing element might also become torn or ripped during the outward expansion. 7

It has been found that the aforenoted difficulties are minimized, if not entirely eliminated, by making the packing element 13 of a plurality of sleeves 15 separated by a spacer member 16, such as the washer or disc. The outward expansion occurs through foreshortening each packing sleeve 15 and bulging it outwardly. The shorter sleeves tend to he anchored at each abutment 14, 12 by frictionally engaging the latter, and their other ends also tendto be anchored by their frictional engagement against the spacer or'separating washer 16. As a result, it is the intermediate portions of each rubber sleeve 15 which inove outwardly, and, in view of the much shorter length of each sleeve, the buckling tendency is overcome and the sleeves expand outwardly uniformly around their circumferences.

In addition to preventing buckling, the plurality of bulges that are formed effectively provides individual into a setting ring 34. A setting sleeve 35 is threaded onto this ring and extends downwardly along the tubular mandrel 28 and tension mandrel 29, its lower end being threaded into an adapter collar 36 screwed onto the upper end of a barrel or container 37 which actually constitutes the dump bailer portion E of the setting tool C. The

extends to a considerable extent above the upper abutment 114. As a matter of fact, the tubular body maybe made ofsections secured together through the agency of intervening couplings 21. Such upward extension of the tubular body 19 is desired, since cementitious material D is to be deposited upon the set packer and around its upwardly extending body portion. This cementitious materiaLupon hardening, will form a supplemental plug in the well bore. effectiveness as a plug in resisting the well pressures than the rubber packing sleeves 15. In addition, it will serve to secure the packer body 10 firmly in the well bore by anchoring the coupling collars 21 to the cement'D. g

V The packer A may be set and the cement D dumped upon the set packer in a single trip of the equipment in the well bore. This is accomplished by securing a combination setting tool and dump bailer C to the packer A. The lower portion of the setting tool, in efiect, constitutes a dump bailer E.

The setting tool includes a power cylinder 22 consisting of a sleeve 23 threaded onto an upper cylinder head 24 and also onto a lower cylinder head 25. A piston 26 is slidably mounted in the cylinder and has a rod 27 secured to it, which extends downwardly through the lower head 25.

In the operation of the equipment, a downward pressure is imposed upon the piston 26, tending'to move it downwardly in the cylinder 22, and reactively, the cylinder tends to move in an upward direction. Since the packer A is set by moving the upper abutment 14 downwardly and the packer body 10 relatively upwardly, it is desired to transfer the upward force of the cylinder 22 to the packer body 10 and the downward force and movement of the piston 26 to the upper abutment 14. The transfer of the upward force of the cylinder occurs by connecting the lower cylinder head 25 to a tubular mandrel 28, whose lower end is secured onto a tension mandrel 29 threaded onto a tension stud 30. The lower end of the stud is threaded into a plug 31 screwed into the upper end of the packer body 10. V

The piston rod 27 has a cross-piece or anvil 32 extending transversely through it, and also through a pair of opposed elongate slots 33 in. the tension mandrel In fact, it may well have a greater merit 14, leakage between the latter two parts being prevented by a suitable side seal 33 on the upper abutment engaging the inner'wall of the container. The fluent cem' as material D may be introduced into the barrel 37, and window or opening 39 provided in the barrel. 7

For purposes that will appear below, the upper end of the packer body has one or more side ports 49, preferably disposed above the window or opening 39, so as to prevent the cementitious material D from entering the interior of the packer body 10, and possibly plugging it. it is also to be noted that the plug 31 carries one or more side seal rings 41 engaging the inner wall of the body It to prevent leakage .therealong, and that the stud St has an intermediate weakened section 39a, to enable disruption of the stud when suificient tension is placed upon it, thereby automatically disconnecting the setting tool C from the packer A.

The piston 26 is moved downwardly within the cylinder 22 and the cylinder urged in a relative upward direction by developing a gaseous pressure in the upper portion of the cylinder. A power charge or railroad flare 45 is disposed in a combustion chamber46 formed in the upper cylinder head 24, this power charge being ignited b firin' a cartrid e 47 contained in a un barrel 48 clamped between the upper head 24 and a cable head 49, to which the lower end of the wire line G is secured. latter member has. a conductive core or wire 50 having an electrical connection with a heating filament 51 in the cartridge. a

When current is caused to pass through the heating filament 51, the cartridge 47 is fired; the flame issuing therefrom in a downward direction igniting the upper end of the power charge 45 and instituting its combustion. This power charge contains its own source of oxygen, and, as it burns, gas is evolved at a gradually increasing pressure. This gas under pressure forces the piston 26 downwardly in the cylinder 22, the downward movement being transmitted through the piston rod 27, anvil 32, setting ring 34, setting sleeve 35, adapter collar 36 and container 37 to the upper packer abutment 14. At the same time, the cylinder 22 is being urged in an upward direction, 'such upward movement being transmitted through the tubular mandrel 28, tension mandrel 29, tension stud 30 and plug 31 to the packer body '16, which moves the lower body abutment 12 upwardly. In this manner, the upper and lower abutments 14-, 12 are shifted toward one another to bulge and expand the packing structure 13 in a lateral'outward direction. Such expansion occurs progressively as the pressure in the cylinder 22 increases, due to the continued combustion of the power charge 45. Eventually, expansion of the packing structure 13 can occur no longer because of engagement of the abutments 12, 14 with the stop sleeve 17.' However, the gas pressure in the cylinder is continuing to increase, until the ultimate strength of the weakened section 39a of the tension stud 30 is exceeded, which results in a pulling apart of the tension stud and the detachment of the setting tool C from the well packer A. Following such detachment, the setting tool C can be elevated, preferably in a gradual manner, by elevating the wire line G, the lower end of the container 37 being removed upwardly off the upper abutment 14, allowing the fluent cementitious contents D of the container to drop out upon the set packer A and around the packer body 10. Inasmuch as the body ports 40 are above the around the packer body 10, through'an upper will pass through these ports during the dumping operation.

When all the cementitious material D has been emptied from the bailer E, the setting tool C can be removed from the well bore B.

The cementitious material D will set and harden in the well bore around the tubular packer body 10 and also against the wall of the open hole. Upon hardening, an annular cement plug is formed in the well bore of extended extent, which is eflectively anchored to the formation, in view of the irregularities present in the latter (Fig. In addition, the coupling collars 21 in the body are locked in the hardened cement, which prevents longitudinal displacement of the body in both directions. Deposit of the cement around the body 10, particularly along an extended length of the latter, tends to maintain the body centered in the well bore, and resists its subsequent tilting or inclination.

After the cementitious material D has hardened, it is desired to relate a tubing string F to the set packer; so that any well production from below the packer A can be conducted to the top of the well bore through the tubing string. Instead of conducting well production, it is also possible to force or pump fluid down the tubing string F and through the packer body 10 to a point in the well bore below the latter.

The tubing string F has a sealing adapter structure 60 forming a part of its lower end, which is capable of being sealed off against the upper portion of the body 10 to conduct fluid between the interior 11 of the body and the interior of the tubing string F. The adapter consists of an upper head 61 threaded onto the lower end of a joint of tubing F, this upper head merging into a neck portion 62 from which an inner skirt 63 depends. This skirt has one or more side seals 64 adapted to seal 05 against the periphery of the tubular body 10 above its ports 40.

The sealing adapter 60 also includes an outer sleeve 65 threaded onto the upper head 61, and extending downwardly along the neck portion 62 and inner skirt 63 to a substantial extent below the lower end of the latter. This outer sleeve has a lower head 66 provided with one or more side seals 67 adapted to engage the periphery of the tubular body below the body ports 40.

Leakage between the neck portion 62 and the outer sleeve 65 is prevented by one or more seals 68 in the former engaging the inner wall of the latter. These seals prevent leakage in both directions and they preclude the fluid in the annulus around the tubing string F from entering the tubing string. This fluid is allowed to enter the adapter 60, in view of the provision of a bleeder hole 69 in the outer sleeve 65 above the seals 68, which communicates with the interior of the inner skirt 63 through a bleeder port 70 in the neck portion 62 of the device.

The inner skirt 63 is spaced from the outer sleeve 65, forming an annular passage 71 therebetwcen through which well fluid can pass. The well production can flow upwardly through the tubular body 10, thence laterally through the body ports 40 into the outer sleeve 65, from where it will flow upwardly through the annular passage 71 between the outer sleeve 65 and the skirt 63, and thence through a fluid port 72 in the neck portion of the device, and on into the tubing string F.

The sealing adapter 60 is lowered in the well bore B on the lower end of the tubing string F. A tapered guide 73 is formed in the lower head 88, which will engage the upper tapered portion 74 of the packer body 10, and be centered with respect to the packer body. Such centering action properly relates the adapter 66 with the body 10, and allows it to be moved thereover to the extent determined by engagement of a stop shoulder 75 in the inner skirt 63 with the tapered upper end 74 of the packer body. When these shoulders 75, 74 engage, the skirt seals 64 engage the packer body 10 above the body ports 40, and the lower head seals 67 engage the packer body 10 below the body ports 40. While the skirt seals 64 are being moved downwardly along the body 10, the fluid that would otherwise be trapped between the packer plug 31 and the neck portion 62 is allowed to escape through the bleeder port 70 and the bleeder hole 69 to the exterior of the apparatus.

The sealing adapter 60 is hydraulically balanced, in order that fluid pressure within the well packer A, adapter 60 and tubing string F will not tend to shift the tubing string longitudinally with respect to the packer. It is to be noted that the fluid in the annulus between the packer body 10 and outer sleeve 65 can act downwardly on the lower head 66 over the annular area R (Fig. 5). This samefluid under pressure can act in an upward direction on the adapter across the annular area S between the periphery of the packer body 10 and the inner surface of the outer sleeve. These two areas are equal; so that there is no tendency of the fluid within the apparatus to shift the adapter in either direction.

In addition, it is to be noted that the fluid under pressure within the tubing string F can act downwardly upon the neck portion 62 of the apparatus over the crosssectional area T. But this same fluid is acting in an upward direction over the same cross-sectional area of tubing at the top of the well bore.

The foregoing comments show quite clearly that the internal pressure within the apparatus can have no tendency to shift the apparatus in either direction. As a result there are no fluid loads due to internal pressure upon the equipment, either acting in an upward direction, which might tend to kink the tubing string F, or acting in a downward'direction, that might tend to place an excessive strain on the tubing string or upon the packer itself. Moreover, in view of the hydraulically balanced condition, the tubing string F and adapter can be moved easily over the packer body 10 when the equip ment is being related to one another, and the adapter can be easily elevated from the packer body 10 in the event it is desired to withdraw the tubing string F.

Accordingly, subsurface well equipment has been provided which enables the well packer to be expanded to a substantial extent and anchored firmly in an open hole in such manner as to resist high pressures, and yet allow production to be had through the well packer A itself. The tubing string F can be readily placed in leakproof relation to the well packer merely by disposing its lower portion 60 along the packer.

The inventors claim: I

1. In apparatus of the character described: -a well packer set in a well bore and having an upwardly projecting body portion, said portion having a fluid passage therein terminating in an upper opening and a lower open inlet to permit upward flow of fluid in said" passage; a tubular member adapted to be lowered in the well bore toward said set packer and telescoped over the upper end of said body portion to receive fluid flowing from said passage and through said upper opening; and seal means below said opening between said member and body portion.

2. In apparatus of the character described: a well packer set in a well bore and having an upwardly projecting body portion, said portion having a fluid passage therein terminating in an upper side port; a tubular structure adapted to be lowered in the well bore toward said set packer and telescoped over said body portion, said structure having a tubular member spaced from said body portion to form an annular chamber therewith; seal means below said port between said member and body portion; seal means above said port between said member and body portion; said structure having a fluid port leading upwardly from said chamber.

3. In apparatus of the character described: a well packer set in a well bore and having an upwardly pro- 7 ieeting; body portion. whose upper-end is closed, said portion. having a. fluid passage therein terminating in. a side punt below-said. closed end; an adapter device. adapt.

ed. to be. lowered'in the well bore toward said. set

packer and telescoped over the upper end of said body portion, said device having, an upper connection for scouring said device to a tubular stringjsaid device ineludingv an outer sleeve spaced from said upper body portion to. form an annular chamber therewith, an inner sleeve sealing against the exterior of said body portion above said port,, a head on said outer sleeve sea-ting below said closing rneausgan adapter adapted to be lowered in the well bore toward said set packer, said adapter beingv telescoped over said upper body portion e and including. an upper head adapted to be secured to the lower end of a tubular string, an outer sleeve depending from said. head and making sealing engagement with said body portion below said port, an inner sleeve depending from. said head and making sealing engagement with said body portion above said port, said head hav ing a fluid. port leading from the interior of said outer sleeve to conduct fluid into the tubular string, said head also having a bleeder. port extending from the interior of said inner skirt above said closing means and cornmunicating with the exterior of said device.

5. In apparatus of the character described: a well packer set inv a well. bore and having an upwardly projecting, body portion whose upper end is closed, said portion having a fluid passage therein terminating in a side port below said closed end; an adapter device adapted. to. be-lowered. in the well bore toward said set packer and telescoped over the upper end of said body portion, said. device having an upper connection for securing said device to a tubular string; said device including an outer sleeve spaced. from said upper body portion to form. an annular chamber therewith, an inner sleeve sealingagainst the exterior. of said body portion above said port, a head; on. said outer sleeve sealing against said body portion below said port; said device also having a fluid port leading upwardly from said chamber to allow fluid flow into the tubular string; and means providing a fluid passage between the interior of said inner sleevev above the. upper end of said body portion and. the exterior of said adapter device.

6. An. adapter device to be placed in leakproof connection with a well packer disposed in a well bore comprising an. upper connection for securing said device to a assess? tubular string to be lowered thereby in the well bore, an outer sleeve depending from said connection, an inner sleeve depending; from said connection and spaced inwardly from said outer sleeve, said outer sleeve. having a head below and spaced from the lower end of said inner sleeve, said head; and inner sleeve having means for sealing against a portion of the well packer, said connection having a fluid passage leading upwardly from the space between said head and the lower end of said inner sleeve and extending through said connection above said inner leeve. 7

7. An adapter device to be placed in leakproof connection with a well packer disposed in a well bore comprising; an upper connection for securing said device'toa tubular stringto be lowered thereby in the well bore,

an outer sleeve depending 7 from said :connection; an inner sieevedepending from said connection: and spaced inwardly from said outer sleeve, said. outer-sleeve hav ing a head below and. spaced from the. lower end of said inner sleeve, said head and innersleeve having means for sealing against a portion of the'w'ell packer, said connection having a fluid. passage leading upwardly from the space between said head and the lower'end of said inner sleeve and. extending, through said connection above said inner sleeve, and means providing a fluid passage.

between the interior of said inner sleeve and the. ex-. terior of said outer sleeve,

8. An adapter device to be placed in leakproof connection with a well packer disposed in a well bore comprising an upper head adaptedto be secured to the lower end of a tubular string to be lowered thereby in the well bore, an outer sleeve secured on said head and depending therefrom, an inner sleeve secured to and depending from said head, said outer sleeve having seal means therein disposed below seal means provided in.

said inner sleeve, means providing a fluid tight seal between said head and outer sleeve above said inner sleeve, said head having bleeder means extending from the interior of said inner sleeve. above said inner sleeve seal means and communicating with the exterior of said outer. sleeve above said fluid tight seal, said head also having a fluid port leading from. the interior. of said outer sleeve between said fluid tight seal and inner sleeve and opening upwardly into said head to conduct fluid into the tubular string.

References Cited in the file of this patent UNITED STATES PATENTS 2,162,179 Mueller June 13, 1939 2,196,664- Kofahl Apr. 4, 1940 2,311,212 Coberly Feb. 16, 1943 2,618,339 Glover Nov. 18, 1952 2,713,907 Kline et'al. July 26, 1955' 2,737,247 Baker et al Mar. 6, 1956

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