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Publication numberUS3182726 A
Publication typeGrant
Publication dateMay 11, 1965
Filing dateDec 26, 1962
Priority dateDec 26, 1962
Publication numberUS 3182726 A, US 3182726A, US-A-3182726, US3182726 A, US3182726A
InventorsStone Jr Dewey C
Original AssigneeBaker Oil Tools Inc
Export CitationBiBTeX, EndNote, RefMan
External Links: USPTO, USPTO Assignment, Espacenet
Multiple zone selective flow control apparatus
US 3182726 A
Images(3)
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Description  (OCR text may contain errors)

May 11, 1965 D. c. STONE, JR

MULTIPLE ZONE SELECTIVE FLOW CONTROL APPARATUS 3 Sheets-Sheet 1 Filed Dec. 26, 1962 Ffa. 1a. F1 0. 16. F1 0 10.

-V///I////%,V

INVENTOR. DEM/5y 6; S70v5, J.

fifTOEA/E'Yi- May 11, 1965 D. c. STONE, JR

MULTIPLE ZONE SELECTIVE FLOW CONTROL APPARATUS 3 Sheets-Sheet 3 1&0. 5'.

Filed Dec. 26, 1962 INVENTOR. DEM/EX C. 570M5 IZQ. BY

3,182,726 MULTIPLE ZONE SELECTIVE FLO CONTROL APPARATUS Dewey C. Stone, Jr., Dallas, Tex., assignor to Baker Gil Tools, Inc., Los Angeles, Calif., a corporation of California Filed Dec. 26, 1962, Ser. No. 246,924 15 Claims. (Cl. 166-145) The present invention relates ot subsurface well bore apparatus, and more particularly to apparatus for controlling the flow of fluid between a plurality of formation zones in a well bore and the top of the well bore.

In a well bore having a plurality of producing zones, it is desired to conduct the fluid from each zone separately to the top of the Well bore. Packer apparatus may be set in the well bore to isolate the producing zones from one another. Well production from the first zone may be conducted through a tubing string to the top of the well bore, production from a second zone being conducted United States Patent through a region externally of the tubing string, such as Y the annulus around the tubing string, to the top of the Well bore. The flow pattern may require change at times, to cause production from the second zone to flow through the tubing string to the top of the well bore and produc-' tion from the first zone to flow through the annulus around the tubing string, or other region externally of the tubing string, to the top of the well bore.

An object of the present invention is to provide improved apparatus for conducting fluid from different well formations separately to the top of the well bore, the flow path of the fluid from one formation to the top of the well bore being interchangeable selectivelyrwith the flow path from another'formation. 7 Another objec-tof the invention is to provide apparatus for conducting fluid from different well formations separately to the top of the well bore, the flow path of one formation fluid being through a tubing string extending to the top of the well bore, and the flow path of another formation fluid being externally of the tubing string, such flow paths being selectively interchangeable by changing the position of the flow control device with respect to the tubing string. r I

A further object of the invention is to provide apparatus for producing fluids in a conventional manner from a lower zone in a well bore through tubing extending to the top of the well bore, and from an upper zone through the annulus around the tubing string, or for producing fluids in a crossed-over manner from the lower zone through the annulus and from the upper zone through the tubing, a flow control portion of the apparatus being shiftable with respect to the tubing string to selectively change the mode of production between conventional and crossed-over, in which shifting of the apparatus can be accomplished through the tubing string. 1

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 accon1-' FIGURES 1a, 1b and 10 together constitute a longitudinal section through apparatus disposed in a well bore for conducting production from a plurality of'zones through separate paths to the top of the well bore, the

apparatus being conditioned for conducting fluid in an 3,182,726 Patented May 11, 1965 Ice crossed-over manner, FIGS. 1b and 1c being lower continuations of FIGS. 1a and 1b, respectively;

FIGS. 2a and 2b are views corresponding to FIGS. la and 1b, theapparatus having been positioned for producing fluid from a plurality of zones in a conventional manner, FIG. 2b being a lower continuation of FIG. 2a;

FIG. 3 is an enlarged cross-section taken along the line 3-3 on FIG. 2a;

FIG. 4 is a longitudinal section taken along the line 44 on FIG. 3;

FIG. 5 is a longitudinal section through a portion of the apparatus illustrating release of the latch or locking device to permit removal of a portion of the apparatus from the tubing string.

The apparatus A specifically illustrated in the drawings is intended to conduct fluid from upper and lower formation zones B, C through separate paths to the top of the well bore. A string of casing D is suitably mounted in the well bore, the casing ordinarily having cement deposited therearound between the upper and lower zones B, C to prevent communication therebetween. A lower packer E of any suitable type is anchored in packed-off condition in the well casing between upper and lower perforations 10, 11 in the casing opposite the upper and lower zones, respectively, and an upper well packer F of any suitable type may be disposed in the well casing above the upper perforations 10. This upper well packer F may be permanently anchored in the well casing D, or may be of the retrievable type, as desired; A tubular string G is disposed in the casing, extending from the top thereof. This tubing string is related in any suitable manner with the upper packer F in leak-proof relation with respect thereto, and extends downwardly therefrom and is suitably related to the lower packer E in leak-proof relation with respect thereto. The tubular string may include an outer body 12 which may, if desired, actually constitute the body portion of the upper packer F, the upper portion of this outer body being threadedly or otherwise suitably connected to a tubing string section 13 thereabove. The lower portion of the body may be threadedly connected to a section 14 of the tubing string extending therebelow, the latter being associated in leakproof relation-with the lower packer E.

. It is desired to variously conduct the fluids from the upper' and lower zones B, C to the top of the wellbore. Such fluid may be conducted in a conventional manner by causing the lower formation fluid to pass through the lower perforations 11 into the casing D and upwardly through the lower packer E into the tubing string G, flowing upwardly through the tubing string to the top of the well bore. The production from the upper formation zone B may pass through the upper perforations 10 into the casing string D to be conducted through a path externally of the tubing string G to the top of the well bore, as through the tubing-casing annulus H around the tubing string. "If desired, however, the production from the lower zone C can be crossed over into the tubingcasing annulus H to be conducted to the top of the well bore, the production from the upper formation zone B being conducted through; the tubing string G to the top of the well bore. I

A single mechanism K is disposed within the tubing G and can be located in diiferent positionstherein to conduct fluid from the upper and lower formation zones B, C to the top of the Well bore in the conventional manner or in the crossed-over manner. As shown, the outer tubular body 12 has a plurality of outlet ports 15 above the upper packer F and a plurality of inlet ports 16 below the upper packer. The body 12 also has a set of equalizing ports 17 below the upper packer F. The outer body 12 also has an upper stop shoulder 18 to locate an s earer;

. a inner tubular body or mandrel 19 in a predetermined position with respect to the po1ts15, 1 6, 17, and it also has a lower stop shoulder 21) to locate the mandrel 19 in another predetermined position with respect'to such ports. The inside diameter r of the outer body 12 above the lower stop shoulder 20 is greater than the inside diameter s ofthe body below such stop shoulder. Moreover, the tubing section 14 below the outer body 12 has a greater internal diameter than the internaldiameter of the passage through the body 12 thereabove.

The outer body 12 also has an upper internal locking groove 21 in its enlarged internal diameter portion and a lower internal locking groove 22 in its smaller diameter portion. Such locking grooves, as explained hereinbelow,

'will lock the tubular mandrel 1 in two different longitudinalpositions within the outer body 12, in order to determine the paths of fiuid flow from the lower and 1 upper formation zones C, B.

The tubular mandrel 19 has a longitudinal partition 23 extending therewithin to separate the mandrel into a longitudinal crossover passage having a lower inlet 25 and an upper outlet or port 26 communicating with the exterior of the mandrel. The partition also provides a lower inlet port 27 and a passage 28 communicating with the central tubular passage 29 through the mandrel 19 that communicates with the tubing string G thereabove. The mandrel can be placed in the crossed-over position illustrated in FIGS. 1a and 1b, in which the mandrel outlet port 26 communicates with the outlet port 15 of the outer body 12, and in which the mandrel inlet port 27 communicates with the inlet port 16 of the tubular body below the upper packer F. When the mandrel is in this position, its lower end 30 slidablyseals with a suitable inner side seal 31 mounted in an internal groove 32 in the outer body below the equalizing ports 17, a suitable side seal 33 mounted on the mandrel then having a sealing engagement with the inner wall of the outer body 12 be tween the body inlet andoutlet ports 16, 15, another side seal'34 on the mandrel sealingly engaging the wall of the outerbody'12 abov the outlet port 15, and, as shown in FIG. 1b, below the lower lock groove 22. An uppermost seal 35 is also mounted on the mandrel, this seal being adapted to seal against the wall of the lower outer body passage of lesser diameter below the lower stop shoulder 26.

With the ports and seals located as illustrated in FIGS; la and lb, production from thelower zone C will pass upwardly through the lower packer E and the tubing G into the lower end of the outer body 12, flowing upwardly through the lower central inlet 25 of the mandrel 19, through its crossover passage 24 and out through its port 26, such fluid continuing to flow out through the outlet port 15 above the upper packer F for continued upward travel through the tubing-casing annulusH tothe top of the well bore and easing. Production from the upper zone B will pass through the upper perforations 1t} and upwardly around the exterior of the outer body 12 below the upper packer F, flowing through. the body inlet ports 16 into the inlet port 27 of the mandrel for continued upward movementthrough. the mandrel passage 28, 29 into the tubing string :G, to be conducted by theflatter to the top of the well bore and casing.- v and lower formation zones B, C cannot'corn'ingle because of the second and third seals 34, 33 sealing against the wall of the outer body 12 on opposite sides of the outlet ports ISjandbecauSe of the sealing of the lower portion of the mandrel against the lowermost body seal 31.

, If production from the upper and lower zones B, C is to be conducted to the top of the well bore in a convenshifted downwardly and disposed within the enlarged in- Fluids from the upper passage 37 between the lower portion of the mandrel 19 and the tubing 14, so that fluid from the lower zone C can flow upwardly through the lower packer E and the tubing G, and through the annular passage 27 into the mandrel passage 28 for continued upward flow through the tubing string G to the top of the well bore. When the mandrel occupies the lower position shown in FIG. 2a, theuppermost seal 35 is disposed within the smaller internal diameter portion of the outer body 12 below the shoulder 20, sealing against the wall of the body above the outlet ports 15, the second seal 34 being disposed below the body inlet ports 16, the internal body seal 31 engaging the periphery of the mandrel 19 above the outlet port 26 of the crossover passage 24 so that the upper end of such passage has no communication with the tubingcasing annulus H, or with the upper well formation production at all. The fluid from the upper zone B will now pass through the body inlet ports 16 into a passage 38 between the first and second seals 35, 34 and between a reduced diameter portion 3? of the mandrel 19 and the inner wall of the outer body 12, such fluid flowing upwardly through such annular passage and out through the body outlet ports 15 into the tubing-casing annulus H to be conducted therethrough to the top of the well bore and easing (FIGS. 2a, 2b).

The mandrel 19 can be positively located in the tubing string G and in the outer body member 12 of the latter in either the position illustrated in FIGS. 1a and 1b,'which is the crossover position, or in theconventional position illustrated in FIGS. 2a and 2b. It can also be releasably locked in these two positions. The mandrel can be locked in the position illustrated in FIGS. 1a and lb or in FIGS. 2a and 2b by a lock or latch device mounted on the upper portion 40 of the mandrel, which latch or lock device is adapted to shift into either the upper locking groove 21 or'the lower locking groove 22. As shown, the mandrel portion 40 has a pair of opposed elongate slots 41 in which upwardly holding latches or dogs 42 are dis- ..posed. Each of these latches is mounted on a pivot pin QSextending across a slot 41 [and suitably secured to the mandrel. The upper dog or lug portion 44 of each latch is urged outwardly and into a locking groove 21 or 22, when aligned therewith, by a helical compression spring 45 hearing thereagainst and also against an inner portion 46 of the mandrel or body portion 4-0. Outward shifting of the upper latch portion 44 is limited by engagement of a lower lock finger 47, on the opposite side of the pivot pin 43, with a body stop web 48 extending across the slot 41. When the upper dog or lug44, is disposed outwardly in a lock groove, a retracting nose 49 on the lower portion of the latch 42 is adapted to extend inwardly of the central passage Stl'thrbugh the mandrel 19.

A second pair of opposed elongate slots S1-is formed in the mandrel or body portion 40 angularly displaced from the other slots 41, receiving a second pair of latches 52 which are the same as the other pair of latches 42 except that they are reversely arranged, t e locking or dog portion 53 being disposed on the lower portions of each latch 52-and the upper retracting nose 54 on the upper portion. Such second set of latchesor dogs 52 is adapted to expand into a locking groove 21 or 22 and anchor the mandrel 19 against downward movement within the outer ternal diameter tubing 14 below the outer body 12, the, V

inlet port of the mandrel communicating with the annular body 12. e h a When the upwardly and downwardly facing latches 42, 52 are disposed in the npper lockinggroove 21, the mandrel'is in the position illustrated inFIGS. la and lb, which is the crossover position. -When the latches'42, 52 expand into the lower locking groove 22,'the tubular mandrel 19 is in the position illustrated in FIGS. 2a and 2b, which is the conventional position for conducting production from the upper and lower producing formations B, C to the top of the well bore.

The location of'the mandrel 19 and the latches'42, 52 in the upper position illustrated in FIGS. 1a and lb is determined-by limiting downward movement of the mandrel 19 in the outer body. As shown, the mandrel 19 with its latches 42, 52 can be lowered from the top of the well bore through the tubing string C on a runningin tool 60 releasably connected to the upper portion 61 of the mandrel. The running-in tool may have an upper threaded pin 62, or the like, adapted for connection to a wire line device (not shown) connected to a wire line (not shown) extending to the top of the well bore. A portion of the running-in tool is constituted as a head 63 having an outside diameter less than the inside diameter of the tubular string G above the body 12 but greater than the inside diameter of the upper passage through the outer body 12, so that the lower end of the head 63 will come into engagement with the upper stop shoulder 18. This head 63 is releasably secured to the upper retrieving head portion 61 of the mandrel by a pair of tangentially arranged shear screws 64 received within opposed recesses 65 in the running-in head and the mandrel head. The running-in tool also includes a retracting tube 66 threadedly secured to the head 63 and receivable in the upper passage portion 56 of the mandrel and engageable with the nose portions 54 of the downwardly holding latches 52 to swing their lower ends or dogs 53 inwardly within the confines of the outer body 19, thereby preventing such downwardly holding latches from entering any coupling recesses, or the like, in the tubing string G.

The mandrel and running-in tool combination 19, 60 are lowered in the tubing G, the upwardly holding latches or dogs 42 merely ratcheting past the tubing couplings, shifting inwardly and outwardly against the force of the expanding springs 45. The retracting tube 66, as explained above, holds the downwardly holding latches 52 in their retracted position. The mandrel and running-in tool apparatus will continue descending through the tubing string G, with the fluid in the tubing string beingable to bypass through the tool, flowing upwardly through the passages 24, 28 in the mandrel and up through the retracting tubing 66, discharging through the side ports 70 in the running-in tool 60. Descent of the mandrel and running-in tool can continue until the head 63 engages the upper stop shoulder 18, at which time the latch dogs 42, 52 are disposed in alignment with the upper lock groove 21 in the outer body 12, the springs promptly expanding the upwardly holding latch dogs 42 into the recess 21, which will engage the upper side of the recess 21 and prevent substantial upward movement of the mandrel 19 within the outer body member 12. The mandrel 19 will then be in the position illustrated in FIGS. 1a 'and 1b, which is the crossover position described above. An upward strain or jarring action can now'be taken on the wire line (not shown), which will shear the screws 64 and release the running-in head 63 from the mandrel head 61, the running-in tool being ele vated to remove the retracting tube 66 from contact with the noses 54- of the downwardly holding latches, the latter then expanding outwardly into the upper recess 21 to prevent downward movement of the mandrel 19 withthe outer body member 12. The running-in tool with its retracting tube 66 can now be removed from the tubing string G by elevating the wire line.

,As described above, the apparatus is now in the crossover position, with the production from the lower zone C flowing through the mandrel passage 24 and into the tubing-casing annulus H, production from the upper zone r B flowing into the mandrel passages 28, 29 and up through the tubing string G to the top of the well bore.

If the flow pattern is to be changed from the cross- ,over arrangement shown in F163. la' and 1b to the conventional arrangement illustrated in FIGS. 2a and 2b,

, a suitable pulling tool 8ti,such as disclosed in FIG. 5, is

lowered on a wire line I (not shown) through the tubing string G. Such pulling tool includes a retracting tube 81 adapted to enter the mandrel 19 and engage the nose 6 portions 49, 54 of upwardly holdingand downwardly holding sets of latches 42, 52, shifting the dogs 44, 52, inwardly from the upper lock groove 21 and entirely within the confines of the mandrel. The pulling tool has a plurality of spring-like arms 82 depending therefrom which will expand over the retrieving head 61 of the mandrel and dispose its inwardly directed fingers 83 below 80 will cause the fingers 83 to engagethe underside of the head. An upward pull now taken on the pulling tool the head 61 and result in upward elevation of the mandrel 19 from the body member 12 and its complete removal therefrom, the retracting tube 81 holding the latches 42, 53 in their retracted positions so that they will not inadvertently catch in coupling spaces or other recesses in the tubing string G. The entire mandrel apparatus 19 is removed from the tubing string at the top of the hole.

If desired, prior to lowering the pulling or retrieving tool 80 through the tubing G for the purpose of removing the mandrel 19 from the body 12, a suitable tool (not shown) can be lowered in the tubing on a wire line, which has a prong (not shown) on its lower portion adapted to move downwardly through the mandrel 19 and engage a pressure equalizing plug 85 threaded in the mandrel between the seal 33, 34, this plug having a central passage 86 and a closed inner end 87. The equalizing prong will engage and break the plug 85, establishing communication between the interior and the exterior of the mandrel 19-between the seals 33, 34, which will effect an equalizing of the pressure above and below the packer F and facilitate withdrawal of the mandrel 19 from the outer body 12.

Following withdrawal of the mandrel 19 from the tubing string G, a second running-in tool 60a (FIG. 2a) can be secured thereto by means of shear screws 64, the retracting tube 66 extending into the passage 50 to hold the downwardly facing or holding latches 52 in a retracted position. The second head 63a of thi tool 60:: has a smaller external diameter than the head 63 previously referred to, being of lesser diameter than the upper passage portion r through the outer body 12 but slightly greater than the internal diameter .5 of the lower passage. Accordingly, the apparatus is run down through the tubing G on a wire line and will pass into the outer body 12, but it will not come to rest until the second head 63a engages the lower stop shoulder 20, at which time the latches 42, 52 will be disposed in alignment with the lower locking groove'22 of the body, the parts being then located in the position illustrated in FIGS. 2a and 2b. Before the apparatus is lowered through the tubing string, however, the formerly broken equalizing plug 85 will have been replaced with another plug whose central passage 86 is intact and closed.

With the parts in the position illustrated in FIGS. 2a and 212, an upward pull or jar is taken on the wire line, the upwardly facing latches42 engaging the upper wall of the lower lock groove 22 to prevent substantial upward movement of the mandrel 19. The shear screws 64 are disrupted and the retracting tube 66 pulled upwardly from engagement with the downwardly holding latches 52, the latter then expanding outwardly under the influence of their springs 45 into the lock groove 22 to prevent downward movement of the mandrel with respect to the outer body. With the parts located in the position disclosed in FIGS. 2a and 2a and upon removal of the running-in tool 60a from the tubing strong G, fluid from the lower zone C can flow upwardly into the mandrel passages 28, 29 to be connected through the tubing string G to the top of the well bore. Fluid from the upper zone B will flow through the body inlet ports 16 and through the annular passage 38 between the reduced diameter portion 39 of the mandrel and the outer body 12 into and through the outlet ports 15 above the upper packer F to be conducted through the tubingcasing annulus H to the top of the well bore.

Susanne In the event it is desired to again place the mandrel in the crossover position disclosed in FIGS. la and 1b, a suitable pressure equalizing tool is again lowered on a wire line through the tubing string G, passing into the upper mandrel portion and striking the frangible equalizing plug 85, breaking the latter, which is now-in communication with the equalizing ports 17 of the body 12, the pressure across the mandrel being equalized by opening of the equalizing passage '86. The equalizing tool can now. be withdrawn from the tubing string and the retrieving tool 80 lowered on a wire line, its retracting tube 81 entering the mandrel passage 50 to retract both sets of latches 42, 52 within the confines of the mandrel, its fingers $3 snapping over the mandrel head 61. 'Upwarcl movement of the wire line and the pulling tool 80 will cause the fingers to engage the lower end of the head 61 and elevate the mandrel 19 from the outer body member 12 and through the tubing string G to the top of the well bore.

The running-in tool as with the larger head 63 can again be connected to the mandrel by means of the shear screws 6%, or other releasable devices, the equalizing plug 555 having been replaced so that the equalizing passage 86 is again closed, and the mandrel 19 again lowered throughrthe tubing G until the head 63 engages the upper stop shoulder 18, placing the apparatus in the Crossover flow condition illustrated in FIGS. la and lb. The upwardly facing latches 42; will again prevent upward movement of the mandrel, allowing an upward .pull or jarring action of the wire line on the running-in tool 60 to shear the screws 64 and enable the running-in head 63 with its retracting tube 66 to be withdrawn throughthe tubing G, the downwardly facing latches 52 expanding outwardly into the recess 21 to prevent downward movement of the mandrel 19 within the outer body member 12.

The same mandrel mechanism can be used and be placed in different selected positions within the outer body 12 of the tubing string G to either secure flow in the conventional manner, such as disclosed in FIGS. 2d and 26, or to secure flow in the crossover fashion illustrated in FIGS. la and lb. It is only necessary to employ a different size stop head 63, 63a on the running-in tool 60 60a to locate the mandrel 1% in one position or the other and to lock it against upward and downward movement in the selected position. At any time, the mandrel 1.9 can be'readily withdrawn from the tubing string G and shifted to another position within the outer body member 12 by appropriate selection of a stop head of the proper diameter, which will engage the desired stop shoulder.

Iclaim:

' 1. In apparatus for conducting fluids between upper and lower zones in a well bore and the top of the well bore: a lower packer set in the well bore between the zones; an upper packer set in the well bore above the upper zone; a tubular string in the well bore operatively connected to said packers and including tubular body means fixed to a portion of said tubular string thereabove to prevent rotational and longitudinal movement of the tubular string above said body means relative to said body means; mandrel means movably mounted in said body means and with respect to said tubular string; said mandrel means'and body means providing separate passages for conducting fluids from the upper and lower zones to the interior of the tubular string above said upper packer' and to the space in the well bore above said upper packer externally of the tubular string; coengageable means on said mandrel means and body means for locating said mandrel means in a first position in said body means wherein said passages conduct fluid separately" 1 from the lower zone to said interior of'the tubular string and from the upper zone to said space; and coengageable means on said mandrel means and body means for locating said mandrel means in a second position in said body means wherein said passages conduct fluid separately 83' from the lower Zone to said space and trom the upper zone to said interior of the tubular string.

2. In apparatus for conducting fluids between upper and lower zones in a well bore and the top of the well bore: a lower packer set in the well bore between the zones; an upper packer set in the well bore above the upper zone; a tubular string in the well bore operatively connected to said packers and including tubular body means fixed to a portion of said tubular string thereabove to prevent rotational and longitudinal movement of the tubular string above said body means relative to said body means; mandrel means movably mounted in said body means and'with respect to said tubular string; said mandrel means and body means providing separate passages for conducting fluids from the upper and lower zones to the interior of the tubular string above said upper packer and to the space in the well bore above said upper packer externally of the tubular string; coengageable means on said mandrel means and body means for locating said mandrel means in a first position in said body means wherein said passages conduct fluid separatelyffrom the lower zone to said interior of the tubular string and from the upper zone to said space; coengageable means on said mandrel means and body means for locating said mandrel means in a second position in said body means wherein said passages conduct fluid separately from the lower zone to said space and from the upper zone to said interior of the tubular string; and means for releasably securing said mandrel means within said body means in said first position and in said second position.

3. In apparatus for conducting fluids between upper and lower zones in a well bore and the top of the well bore: a lower packer set in the Well bore between the zones; an upper packer set in the well bore above the upper zone; a tubular string in therwell bore operatively connected to said packers and including tubular body means; mandrel means movable down through said tubular string into said body means; said mandrel'rneans and body means providing separate passages for conducting fluids from the upper and lower zones to the interior of the tubular string above said upper packer and to the space in the well bore above said upper packer externally of the tubular string; stop means in said body means engaged by means on said mandrel means for locating said mandrel means in a first position in said body means wherein said passages conduct fluid separately from the lower zone to said interior of the tubular string and from the upper zone to said space; and stop means on said body means engaged by means on said mandrel means for locating said mandrel means in a second position in said body means wherein said passages conduct fluid separately from the lower zone to said space and from the upper zone to said interior of the tubular string.

4. In apparatus for conducting fluids between upper and lower zones in a well bore and the top of the well bore: a lower packer-set in the well here between the zones; an upper. packer set in the well bore above the upper zone; a tubular string in the well bore operatively connected to said packers and including tubular body means; mandrel means movable down through said tubular stringinto said body means; said mandrel means and body meansproviding separate passages for conducting fluids from the upper and lower zones to the interior of the tubular string above said upper-packer and to the space in the well bore above said upper packer externally of the tubular string; stop means in said body means en- 'gaged by'means on said mandrel means'for locating said mandrel means in a first position in saidbody means wherein said passages conduct fluid separatelyrrom the lower zone to said interior of the tubular string and from the upper zone to said space; stop means on said body means engaged by means on said mandrel means for locating said mandrelimeans in a second'position in said body means wherein said passages conduct fluid separately from the lower zone to said space and from the sleeves 9 upper zone to said interior of the tubular string; and means on said mandrel means adapted to be releasably coupled to said body means to secure said mandrel means in said first position and in said second'position.

5. In apparatus for conducting fluids between upper and lower zones in a well bore and {the top of the well bore: alower packer set in the well bore between the zones; an upper packer set in the well bore above the upper zone; a tubular string in the well bore operatively connected to said packers and including tubular body means; mandrel means movable down through said tubular string into said body means; said mandrel means and body means providing separate passages for conducting fluids from the upper and lower zones to the interior of the tubular string above said upper packer and to the space in the Well bore above said upper packer externally of the tubular string; said body means having upper and lower stop shoulders therein; a first stop head adapted to bemounted on said mandrel means and engageable with one of said shoulders for locating said mandrel means in a first position in said body means wherein said passages conduct fluid separately from the lower zone, to said interior of the tubular string and from the upper zone to said space; and a second stop head adapted to be mounted on said mandrel means and engageable with another of said shoulders for locating said mandrel means in a second position in said body means wherein said passages conduct fluid separately from the lower zone to said space and from the upper zone to said interior of the tubular string.

6. In apparatus for conductingfluids between upper and lower zones in a well bore and the top of the Well ;bore a lower packer set in the well bore between the zones; an upper packer set in the well bore above the upper zone; a tubular string in the well bore operatively connected to said "packers and including tubular body means; mandrel means movable down through said tubular string into said body means; said mandrel means and body means providing separate passages for conducting fluids from the upper and lower zones to the interior of the tubular string above said upper packer and to the space in the well bore above said upper packer externally of the tubular string; said body means having upper and lower stop shoulders therein; a first stop head adapted to be mounted on said mandrel means andrengageable with one of said shoulders for locating said mandrel 'means in a first position in said body means wherein said mounted on' said mandrel means and engageable with' another of said shoulders for locating said mandrel means in a second position in said body means wherein said passages conduct fluid separately from the lower zone to said space and from the upper zone to said interior of the tubular string; said body means having upper and lower into saidlower groove when another of said stop heads engages said lower shoulder.

Q7. In apparatus for conducting fluids,between upper and lower zones ina well bore and the top of the well bore: a lower packer set in the well bore between the zones; an upper packer set in the well bore above the upper zone; a tubular string in-the well bore operatively connected to said packers and including tubular body means; mandrel means movable down through said tubular string into said body means; said mandrel means and body means providing separate passages for conducting fluids from the upper and lower zones to the interior of the tubular string above said upper packer and to the space in the well bore above said upper packer externally said interior of the tubular string and from the upper zone to said space; a second stop head adapted to be mounted on said mandrel means and engageable with another of said shoulders for locating said mandrel means in a second position in said body means wherein said passages conduct fluid separately from the lower zone to said space and from the upper zone to said interior of the tubular string; and shear means releasably securing each head to said mandrel means when mounted thereon.

8. In apparatus for conducting fluids between upper and lower zones in a well bore and the top of the well bore: a lower packer set in the well bore between the zones; an upper packer set in the well bore above the upper zone; a tubular string in the well bore operatively connected to said packers and including tubular body means; mandrel means movable down through said tubular. string into said body means; said mandrel means and body means providing separate passages for conducting fluids'from the upper and lower zones to the interior of the tubular string above said upper packer and to the space in the well bore above said upper packer externally of the tubular string; stop means in said body means engaged bymeans on said mandrel means for locating said mandrel means in a first position in said body means wherein said passages conduct fluid separately from the lower zone to said interior of the tubular string and from the upper zone to said space; stop means on said body means engaged by means on said mandrel means for locating said mandrel means in a second position in said body means wherein said passages conduct fluid separately from the lower zone to said space and from the upper zone to saidinterior of the tubular string; means on said mandrel means adapted to be releasably coupled to said body means to secure said mandrel means in said first position and in said second position; and retrieving means adapted for movement through the tubular string to release said a coupling means and withdraw said mandrel means through the tubular string to the top of the well bore.

9. In apparatus for conducting fluids between upper and lower zones in a well bore and the top of the well bore: a lower packer set in the well bore between the zones; an upper packer set in thewell bore above the upper zone; a tubular string in the well bore operatively connected to said packers and including tubular body means; mandrel means movable down through said tubular string into said body means; said mandrel means and body means providing separate passages for conducting fluids fromthe upper and lower zones to the interior ofthe tubular string above said upper packer and to the space in the well bore above said upper packer externally of the tubular string; said body means having upper and lower stop shoulders therein; a first stop head adapted to be mounted on said mandrel means and engageable with one of said shoulders for locating said mandrel means in a first position in said body means wherein said passages conduct fluid separately from the lower zone to said interior of the tubular string and from the upper zone to said space; a second stop head adapted to be mounted on said mandrel means and engageable with another of said shoulders for locating said mandrel means in a second position in said body means wherein said passages conduct fluid separately from the lower zone to said space and from the upper zone to said interior of the tubular string; said body means having upper and lower lock grooves therein; coupling means on said man- -drel means expandible into a selected lock groove to rreleasably secure said mandrel means in either of said positions, said mandrel means being expandible into said l l upper groove when one of said stop heads engages said upper shoulder, said coupling means being expandib'le into said lower groove when another of said stop heads engages said lower shoulder; and retrieving means adapted for movement through the tubular string to release said coupling means from a lock groove in which it is disposed, said retrieving means embodying means for coupling to said mandrel means whereby said retrieving means can Withdraw said mandrel means through the tubular string to the top of the well bore.

10. ln'apparatus to be disposed in a well bore having upper and lower producing zones and in which one zone is to be produced through a tubular string disposed in the well bore and the other zone through the annulus around the tubular string: tubular body means adapted to form part of the tubular string; mandrel means movably mounted in said body means; said mandrel means and body means providing separate passages adapted to con duct fluids from the upper and lower zones to the interior of the tubular string above said body means and to the annulus around the tubular string above said body means; coengageable means on said body means and mandrel means for locating said mandrel means in a first position in said body means wherein said passages conduct fluid separately from the lower zone to said interior of the tubular string and from the upper zone to said annulus; and coengageable means on said body'rneans and mandrel means longitudinally spaced from said other coengageable means for locating said mandrel means in a second position in said body means wherein said passages conduct fluid separately from thelower zone to said annulus and from the upper zone to said interior of the tubular string.

11. In apparatus to be disposed in a well bore having upper and lower producing zones and in which one zone is to be produced through a tubular string disposed in the well bore and the other zone through the annulus around the tubular string: tubular body means adapted to form part of the tubular string; mandrel means movably mounted in said body means; said mandrel means and body means providing separate passages adapted to conduct fluids from the upper and lower zones to the interior of the tubular string above said body means and to the annulus around the tubular string above said body means; coengageable means on said body means and mandrel means for locating said mandrel means in a first position in said body means wherein said passages conduct fluid separately from the lower zone to said interior of the tubular string and from the upper zone to said annulus; coengageable means on said body means and said mandrel means longitudinally spacedfrom saidother coengageable means for locating said mandrel means in a second position in said body means wherein said passages conduct fluid separately from the lower zone to said annulus and from the upper zone to said interior of the tubular string; and means for releasably securing said mandrel means in said body means in said first position and in said second position.

12. In apparatus to be disposed in a well bore having upper and lower producing zones and in which one zone is to be produced through a tubular string disposed in the well bore and the other zone through the annulus around the tubular string: tubular body means adapted to form part of the tubular string; mandrel means adapted 'for movement downwardly through the tubular string into the body means; said mandrel means and body means providing separate passages adapted to conduct fluids around the tubular string above said body means; stop means in said body means engaged by means on said mandrel means for locating said mandrel means in a first position in said body means wherein'said passages conduct fluid separately from thelowerzone to said interior of the tubularjstring andffrom the'upper zone to said annulus; and stop means on said body means engaged by means on said mandrel means for locating said mandrel means in a second positionin said body means wherein said passages conduct fluid separately from the lower zone to said annulus and from the upper zone to said interior of the tubular string.

13. In apparatus to be disposed in 'a well bore having upper and lower producing zones and in which one zone is to be produced through a tubular string disposed in the well bore and the other zone through the annulus around the tubular'string: tubular body means adapted to form part of the tubular string; mandrel means adapted for movement downwardly through the tubular string into the body means; said mandrel means and body means providing separate passages adapted to conduct fluids from the upper and lower zones to the interior of the tubular string above said body means and to the annulus around the tubular string above said body means; said body means having upper and lower stop shoulders therein; a first stop head adapted to be mounted on said mandrel means and engageable with one of said shoulders for locating said mandrel means in a first position in said body means wherein said passages conduct fluid separately from the lower zone to said interior of'the tubular string and from the upper zone to said annulus; and a second stop head adapted to be mounted on said mandrel means and engageable with another of said shoulders for locating said mandrel means in .a second position in said body meanswherein said passages conduct fluid separately from the lower zone to said annulus and from the upper zone to said interior of the tubular string. a

14s In apparatus to be disposed in a well bore having upper and lower producing zones and in which one zone is to be produced through a tubular'string disposed in the well bore and the other zone through the annulus around the tubular string: tubular body means adapted to form part of the tubular string; mandrel means adapted for movement downwardly through the tubular string into the body means; said mandrel means and body means providing separate passagestadapted to conduit fluids from the upper and lower zones to the interior of the tubular string above said body means and to the annulus around the tubular string above said body means; said body means having upperand lower stop shoulders therein; a first stop head adapted to be mounted on said mandrel means and engageable with one of said shoulders for locating 'said mandrel means in a first position in said body means lower zone to said annulus and from the upper zone to said interior of the tubular string; said body means having upper and lower lock grooves therein; and coupling means on said mandrel means eng'ageable with a selected lock groove to releasably secure said mandrel means in either of said positions, said coupling means being expandible into said upper groove when one of said stop heads engages said upper shoulder, said coupling means being eXpandible into said lower groove when another of said stop heads engages said lower shoulder.

J 15. "In apparatus to be disposed in a well bore having upper and lower producing zones and in which one zone is to be produced through a tubular string disposed in the wellbore and the other zone through the annulus around the tubular string: tubular body means adapted to form part of the tubular string; mandrel means adapted for movement downwardly through the'tubular string into the body means; said mandrel means and body means providing-separate passages adapted to conduct fluids from the upperand lower zones to the interior of the tubular string above said body means and to the annulus 13 around the tubular string above said body means; said body means having upper and lower stop shoulders therein; a first stop head adapted to be mounted on said mandrel means and engageable with one of said shoulders for locating said mandrel means in a first position in said body means wherein said passages conduct fluid separately from the lower zone to said interior of the tubular string and from the upper zone to said annulus; a second stop head adapted to be mounted on said mandrel means and engageable with another of said shoulders for locating said mandrel means in a second position in said body means wherein said passages conduct fluid separately from the lower zone to said annulus and from the upper zone to said interior of the tubular string; and shear 14 means releasably securing each head to said mandrel means when mounted thereon.

References Cited by the Examiner UNITED STATES PATENTS 2,368,428 1/45 Saurenman 16645 2,649,916 8/53 Brown 166-145 2,717,041 9/55 Brown l6645 2,766,831 10/56 Otis 166-116 2,840,167 6/58 Brown 166-l5'2 2,936,832 5/60 Brown et a1. 166-415 3,008,522 11/61 Fredd et al 1661l5 CHARLES E. OCONNELL, Primary Examiner.

Patent Citations
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Referenced by
Citing PatentFiling datePublication dateApplicantTitle
US3302721 *Feb 28, 1964Feb 7, 1967Shell Oil CoDual zone completion system with special valve
US3414071 *Sep 26, 1966Dec 3, 1968Halliburton CoOriented perforate test and cement squeeze apparatus
US3517743 *Dec 13, 1968Jun 30, 1970Dresser IndSelective interval packer
US3640341 *Nov 6, 1969Feb 8, 1972Texas Iron WorksApparatus for completing plural zone oil and gas wells
US3960366 *Mar 18, 1974Jun 1, 1976Dresser Industries, Inc.Reverse acting lock open crossover valve
US4566535 *Sep 20, 1982Jan 28, 1986Lawrence SanfordDual packer apparatus and method
US4793417 *Aug 19, 1987Dec 27, 1988Otis Engineering CorporationApparatus and methods for cleaning well perforations
US7367401 *Nov 29, 2004May 6, 2008Smith International, Inc.Ported velocity tube for gas lift operations
US7766085Feb 4, 2008Aug 3, 2010Marathon Oil CompanyApparatus, assembly and process for injecting fluid into a subterranean well
US8302695Oct 16, 2009Nov 6, 2012Bp Corporation North America Inc.Downhole systems and methods for deliquifaction of a wellbore
US8413726Aug 3, 2010Apr 9, 2013Marathon Oil CompanyApparatus, assembly and process for injecting fluid into a subterranean well
Classifications
U.S. Classification166/145, 166/313, 166/186, 166/149, 166/147, 166/123, 166/115
International ClassificationE21B43/14, E21B43/00
Cooperative ClassificationE21B43/14
European ClassificationE21B43/14