US2531258A

US2531258A - Dual flowing device

Info

Publication number: US2531258A
Application number: US652048A
Authority: US
Inventors: Cranfill Otis
Original assignee: B F WEEKLEY
Current assignee: B F WEEKLEY
Priority date: 1946-03-05
Filing date: 1946-03-05
Publication date: 1950-11-21
Anticipated expiration: 1967-11-21

Description

Nov. 21, 1950 o. CRANFILL 2,531,253

mum. FLOWING DEVICE k Filed March 5, 1946 s Shets$heet 1 I m/entor 0775 ('TA NF/Ll.

WWW 3% Filed March 5, 1946 3$heBtS-Shee1f2 Nov. 21, 1950 o. CRANFILL 2,531,258

DUAL FLOWING DEVICE Inventor 07/5 C3 24 NF'ILL By ghee/Zia wig way 3m Nov. 21, 1950 o. CRANFILL mum. FLOWING DEVICE Filed March 5, 1946 3 Sheets-Sheet 3 llllill Ill Alli!!! .lflI u I I I 'I If! 7"! II III! 7",: III! I I I I I l I. II I 7 I If" I I!!! III .III III! IIIIIIIIIII i Ill! .Illll/ll I! vlill. .vl Itillllifli Illl'llilllll'lli I I I .0 I I. I .l I v! I r VIII/l, III! ilfllirilifivlvl ll I III. ,II.

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Patented Nov. 21, 1950 UNlTEosTAT-Es PATENT OFFICE DUAL FLOWING DEVICE Otis Cranfill, Groes beck, Tex., assignor of onehalf toB. F. Weekley, Fort Worth, Tex.

Application' March 5, 1946, Serial No. 652,048

, 4 Claims. 1

This invention relates to new and useful improvements in oil well equipment and more particularly to a dual flowing device for oil and gas wells having a plurality of productive zones, strata or productive pay areas in one well. In certain localities, there is often found two or more productive pay areas at different depths in one well and the present invention is designed to facilitate and control the flow from said areas simultaneously or independently, and to facilitate the running and pulling or removal of the piping, especially in very deep wells, and where the distance between the respective productive pay areas is considerable and the length and weight of tubing becomes a problem, especially in sealing off the productive areas from each other for independent flow control or in elevating the upper inner tubing to permit simultaneous flow of both areas through the same outlets.

The principal object of the present invention is to provide a novel and eflicient device whereby two pay areas or stratums can be produced simultaneously or separately, if desired, or to permit the areas or zones to be successively and independently swabbed in or made to flow through the tubing, and wherein when the flow is established, the pressure of the gases in the different areas or zones may be used to facilitate and provide the necessary pressure for insuring the flow and production from either or both areas.

Another important object of the invention is to provide a dual flowing device of the character as stated, which can be inserted into an oil well casing which houses the oil well tubing having the usual casing head, Christmas tree and rigging, for the purposeof permitting either one of the two pay areas to produce and flow separately, or to permit bothare'as to produce orflow simultaneously. 1

A still further object of theinvention is to facilitate the running of the piping or tubing and pulling or removal thereof, especially, in very deep wells, where the distance between the areas is considerable, and to produce and facilitate a combination dual installation in wells of extreme depth due to the extreme weight of the tubing, and make the'saine much less hazardous and much less likely of parting when running the tubing and for sealing off or establishing communication between the respective independent production or pay areas without allowing A still furtherlobject of the invention is to facilitate the running of the tubingorpulling of the upper section thereof with respect to the inside tubing, for the flow of oil and gas from the deepest oil bearing formation or stratum constituting a productive pay area, by having the inside tubing divided into two parts so that the same may be connected with facility or separated so that the pressure from either or both productive pay areas may be used to provide the necessary pressure for causing the flow or discharge of the gas or oil from either area and to conserve the pressure for a longer time duration, as well as to permit the use of plain tubing instead of upset tubing for the inside tube in order to maintain an ample annular space for the top pa 'to produce through to the surface, and to guide and keep the sections of the tubing in alignment at all times to facilitate the running and pulling thereof, without necessitating a fishing job.

This application is a continuation in part of my prior application Serial No. 473,759, filed January 27, 1943, now abandoned.

Other objects and advantages reside in the details of construction and operation as more fully hereinafter described and claimed, reference being had to the accompanying drawings .forming part hereof, wherein like numerals refer to like parts throughout, and in which:

Figure 1 is a vertical sectional view of the barrel or cylinder of the dual flowing device constituting the invention.

Figure 2 is a side view in elevation of the upper core of the sealing device.

Figure 3 is a bottom end view of the core shown in Figure 2.

Figure 4 is a longitudinal sectional view of the structure shown in Figure 1, taken substantially on the line i i thereof and showing the connection for the lower outer tubing section.

Figure 5 is a side iew in elevation of the sealing head of the device.

Figure 6 is a bottom view of the structure shown in Figure 5.

Figure 7 is a vertical longitudinal sectional view showing the dual flowing device installed in a well casing of a well having two productive pay areas, and the parts positioned to isolate the fluid flowing from one fluid bearing stratum from that flowing from another fluid bearing stratum, and

Figure 8 is an enlarged fragmentary sectional view of the device showing the parts positioned to permit simultaneous flow of fluid from both strata through the tubular conduit oi the device.

Referring to the drawings in detail and particularly to Figures '7 and 8, a conventional well is shown as passing through a plurality of oil hearing or productive pay areas or strata, indicated as an upper oil bearing formation or stratum B and a lower oil formation or productive stratum C. The ground level is designated at D, above which the casing, and oil flow control devices. extend. Conventional well rigging is disposed above the well and is equipped with con.- ventional means for raising or lowering the tubular conduit, tube and the well casing in a manner well known in the art. The well is cased with a conventional well casing A which is: provided with spaced groups 25 and- 25 of perforations through which the fluid from. the respective strata B and C ma enter the casing A.

Referring more especially to Figure 4' of the drawings, as well as to Figures 1 and 7, the numeral designates a barrel or cylinder of tubing constituting a portion of the outer tube of the device. This tube may be of any suitable diameter, less than the i. d. of the well casing, such for example as 2 /2", so as to provide an annular space between the tube and the well casing A. This barrel 5, like the other sections of the tube is preferably of the plain tubing typ and is externally threaded at its upper end to connect to an internally threaded coupling into which is threaded a perforated sub-barrel or tube section be. The upper end of the perforated tubing section to is coupled in a conventional manner as by coupling 53a to an upper string or run of tubing 5b which extends above the upper end of the casing A of the well in the usual manner.

As best seen in Figure 7, the tubular well casing A extends from above the top of the ground to the bottom of the well, through an upper pay layer or oil producing stratum B and right down into and through the lower pay or oil producing stratum C, which may be as deep down as 4,000 below the upper oil producing stratum B, which itself ma be located several thousand feet below the ground level C; As indicated in Figure '1, the well casing A is provided with a group of perforations 25 to establish. communication between the upper stratum B and the interior of the casing and this casing A is also provided with a longitudinally spaced group of perforations 26 which open into the lower stratum. C. The upper end of the casing A terminates slightly above. the ground level D and is closed by a cap A of" any preferred construction. The cap A is provided with an axial opening through which. passes the end of the string or run of tubing 517: remote from the perforated section 5a.

Numeral 7 indicates a mandrel or piston body which constitutes a section. of the inner tubing or tubular conduit and has a central passageway 21 throughout its entire length terminating near its upper end in an enlarged oppositely tapered guide portion or cup protector 8 having a tube portion or extension corresponding to portion T, at itsupper end, where it is externally threaded as at 8a to accommodate and removably attach to an. internally threaded collar to by means of which the upper end or section Ia of the smaller inside tubing or tubular conduit is attached to form a continuation of the central passageway 21 and extend above the head 50 of the outer tubing and section 51) thereof, through and above said head, where it may be attached to suitable rigging or elevating means so that it may be moved up or down. In this way, the upper section Ta of the inner tubing extends movably through the head 50 constituting the closed upper end of the barrel constituted by the

sections

5, 5a and 5b, and in spaced relation coaxially within said barrel or tubing.

Numerals

9, 9, denote a plurality or pair of packing or sealing cups similar to those used on pistons and may be of the standard Darcona type on the hollow lower portion of the mandrel or piston body 1' facing inone direction, while numerals 19, I0, denote another pair or plurality of similar cups on the same lower portion of the mandrel or body 1 facing in the opposite dimotion-- to the

cups

9, 9. A fiat metal spacer ring H is placed between the opposite ends of the adjacent cups 9 and I0 and is slightly smaller than the interior diameter or bore of the outer tubing toreadily move therein while causing proper spreading of the sealing or packing cups.

Other necked metal spacers Ha fit around the mandrel or piston body 7 with their necks seated within and between the cups of said pairs of cup packings 9 and M respectively, as more particularly shown in Figure 4 of the drawings.

The lower end of the tubular mandrel or piston body I is externally threaded to engage the internally threaded neck portion P2 of a cup support guide or head [3 which is also tapered in opposite directions and has a smooth faced tubular downward extension or nipple M provided with a lead packing l5 adjacent its lower reduced portion at the juncture of the lower tapered or beveled end thereof, forming a seal for the internal upwardly facing seat 16 of a top sealing collar which has an internally threaded enlarged upper end threaded on the externally threaded lower end' of the barrel 5. The guide [3- has the passagewa 21 continued therethrough by reason of the hollow bore 2-!- forming a continuation of said passagewa through the mandrel or rod 7. The tubular conduit includes the sealing device or piston, and consists therefor of the following parts, namely"; 1, la, 8, 8a, 8b, 9, I8, II, Ila, l2, l3, l4 and f5, and the inner sealing section or tube consists of the

parts

5, 5a, 5b, 5c, 6, 6a, and I6.

The lower portion of the seat It is thickened and smooth internally to receive the portion Id of the seat body 13' and has a reduced ex ernally threaded portion to accommodate the internally threaded portion. at the upper end of a combination hanger sleeve H which has an internally threaded axial socket opening into an axial threaded bore which extends downwardly through a reduced externally threaded lower portion. The junction of the socket and bore form a shoulder l8 for supporting a tubular hanger l9 having a reduced internally threaded extension or nipple 21' by which the upper" externally threaded end of a lower tubular conduit section lb is connected thereto. The hanger also has an axial internally threaded socket entering its top into which is threaded a short externally threaded nipple 20. This nipple 29 extends up into the recess Hia' provided in the lower portion of the seating collar 16. The hanger l9 as before stated, is internally threaded as at 2| to receive the upper threaded end of the lower section lb of the. tubular conduit. which corresponds in diameter to the mandrel 1. The lower reduced and externally threaded end of the hanger sleeve or collar I T has a lower barrel section or tube Ila. corresponding in size to the main. barrel section 5. connected thereto by means of an internally threaded collar 61) corresponding to the collar 6 at the upper end of the barrel 5 and by which the latter is connected to the perforated tubular section a so that the lower tubular barrel section Ila of the outer tubing is connected to the hanger seat l1.

With two oil paying or bearing formations producing productive areas or zones, one a considerable distance below the other in the well, as described, a suitable packer or outer tubing head 4, such as bronze, provided with a packing ring, is placed or fixed on the lower barrel section or tubing Ila between the well casing A and the lower barrel or tubing section Ila so as to seal off the annular space between the casing A in the lower barrel at a point between the strata B and C as shown in Figures 7 and 8, to prevent any upward flow of theoil therebetween. However, above the packer 4, the casing is perforated as at 25 where it passes throughthe upper oil producing area B so that oilcan be produced from the upper area and allowed to flow through other perforations 25a provided higher up in'the inner tubing section or barrel Eaand then flew upwardly in the annular space 250 between the inner tubing 1a and the outer tubing or barrel 5b above the sealing device or piston within the outer tubing. The lower oil producing or paying area isdrained by passing the'oil through the perforations 26 in the bottom end of the casing A and then through the perforations 26a in the tapered lower end or nozzle of the lower outer tubing section or barrel Ila and up through the inner tubing starting with the lower section lb as shown in Figures 4 and 7, this flow being entirely separate from the flow in the casing A above the packer or outer piston head 4, constituting a sealbetween the outer tubing at Fla and the well casing A. It will thus be seen that the separable dual flowing device and inner seal is so constructed as to establish a continuous inner tubing passage connecting the sections la and lb, of uniform size and rela- 6, turning the same to couple or uncouple the same at the threaded connections with positive alignment insured to facilitate same as above described and prevent dropping of the lower section or unit to avoid the necessity of a fishing .job.

The oil from the upper oil producing area B is caused to flow under pressure of the gases from the sands therein for discharge separately from the oil from the lower oil producing area C,-and takes place through the perforationsin the well casing A to the space of annular form between the same and the outer tubing at the cylinder or barrel 5 and then through the perforations 25a of the barrel or tubing section sarand annular space 250 around the inner tubing section la, for discharge through the delivery pipe 30 at the top, where the pressure may be-determined by a pressure gauge 3|. As distinguished from the bottom oil supply, the top oil supply through the annular passage, will be underapressure of .thegases above the packer A, and at the top of the space between the outer tubing and the well casing at the top, where the pressure may be determined by another pressure gauge 32 in the space 25b, permitting the pressure to be stored or back up; therein in order to facilitate the flow from the upper ,oil bearing formation or area B, and in each instance, to conserve the pressure for a longer time. duration. Avery important feature of ,thisinvention is the hanger construction.v *The upper or inner sealingsection or piston terminates at the lower end with the tube nipple M. :For very deep wells, a tubular conduit section lb is needed to reach downinto the lower oil deposit at C, and this tively smooth bore, sealed oil from the annular passage therearound, between the inner tubing and the outer tubing to allow separate or independent fiow of the oil therethrough from the the casing A and the perforatedlower end of the nozzle or outer tubing and then up through I the central smaller tubing or passageway -2l. In this operation and relation of the-parts as shown in Figures 4 and 7, the lead seal I5 supplemented by the sealing rings or cups 9 and It, eifectively seal on" the annular space or passage between the inner tubing and the outer tubing in the lower portion of the-casingA, and the corresponding space or passage in the upper portion of the casing above theseparable dual flow device of the present invention so that the flow is entirely-through the inner tubing or passageway 2'! independently of the annular passage therearound, with the discharge through the oil delivery pipe '28, while the pressure may beidetermined by the gauge 29. Obviously, a Christ-.

mas tree or any other suitable arrangement may beprovided at thetop for controlling the now and for raising and lowering the upper section of the inner tubing and the sealingtdevice, as

well as for running or pulling the tubing and for tubular conduit section"; is threaded in the hanger l9 and has the same bore as the main tubular mandrel and the nipple 2fl. The'advantage of this arrangement will be readily seen as when assembling or removing the..tubular conduit in the oil well, the nipple will serve as a coupling by which the lowertubular section may be attached to: suitable hoist mechanism andthe weights to be handled may be materially reduced. Supposing, for instance, that ,the casing A has beeninstalled in the well together with the lower parts 4, Ila of the lower or outerv sealing section to the hanger sleeve and seat I1, then it will be possible to lower the hanger I9 with the attached tube section 11) therein, suitable implements being used-for gripping the threaded stubpipe 20 during this procedure. Subsequently the collar seat is with barrel 5 is added and thenthe inner sealing section proper from the support guide head l3 up is lowered into its seat l6.

By this means a two-stage installation is possible; with the inner tubular conduit comprisiing parts 1,100, lbjin perfect alignment and the weight of the lower part lb and hanger is supported on the hanger seat [8. i The tubular con- ;duit comprising the parts from the support guide head [3 up are supported by the .lead packing [5 in the collar or pistonseat It. By thus sup- ;porting thetubular conduit at spaced points the running and pulling thereof in deep wells is ,;made less hazardous.

Another advantage is that raising of'the oil from the bottom layer takes place through a relatively small conduit, about 1%; diameter, while the raising of the oil fromthe upper ;de-

posit takes place through arlarger tube, about 2 diameter. r i

n :Fi .1116: .iO the r wineathe dual fl l r sea ing; device is. shown parted or; separated atv the lead seal t5; to. permit, simultaneousor jointflow from. both. oil producing; areas through. the upper portion of they annular flow passage or. space and theinner tube or passage, as. Well as facilitating running or pulling of the tubing or piping in deep wells; and permitting the. flow from. the upper and: lower pay or production. areast beswabbed inin the customary manner: andso that. the oil or.- fluid entering above. the; swab. may be: lifted out; in the. nature. of bailing to. induce. the flow ofthe oil out of the formation. to the surface of the ground through. the well for storage. Es pecially'is thistrue when it' is. necessary to swab in the bottom my area. or production formation and. in. washing. outzthe. mud with water and the water with oil. The. device: also; cuts the gas waste down in. lifting the; fhiid due. to: smaller columns thereby reducing the gas. breaking through the fiuid and allowing the well. to. flow longer on its own gas: reserves, thereby lengthening the life of thewell flush outputto someextent. It also completely eliminates the cost. of drilling a second well and the material required in connection therewith.

Under certain circumstances and particularly for cleaning in the case of very deep wells, it is necessary to pull up the inner sealing or piston structure including the support guide head: l3 where it is seated at [5 as shown in Figures 1, 4 and-'7. It might become necessary to switch or change joints at thetopin order to equally divide the weight at the seal l5 and the usual Christmas tree hanger at the-well surface (not shown) This would likely be necessary on each installation while making the installment, but after the completion of this-installmentand the device is in position, as-shown in Figure l, itis in this position that it is readyto function and serve its purpose as a means of closing the annular space of the tube 5 and the outside of the smaller tube line below the hanger seat H.

A separate deposit of fluid from the top stra- B, (as isclearl y shown in Figure 7) is made in the casing A outside of the large-tube 5- through the useof the packer'and the dual'fiowing device, which makes-it possible toconfine the fluids. from difierent strata to separate linesto storage vessels. The-fluid from the bottom deposit C passes through the bore-2 1 of the tubular conduit Ta to the surface line-2'8 and corresponding storage vessel, while the fluid from the top stratum B passes through the flow. passages 25a in the tube section 5a to the outside of the tubular conduit Pa and hence it will be seen that the fluids from the two strata will be prevented from -mingling. When however it is desired to discharge the fluids-from both strata, the tubular conduit la together with the head t3 and packing rings-9- is moved longitudinally of the tube section untilit passes through the tube section 5a having the flow passages 25a and into the tube section 512. In this position it will be evident that the fluids from both strata B. and C will be di schargedfrom the well through the tubular conduit.

While the foregoing specification sets forth the invention inspecific terms, it is to be. underhole from thebottom thereof to: the surfacerof. the ground and having, a perforated area at each. of said stratums, outer. flow, tubing; disposed within and in spaced concentric relation, to said casing extending: continuously from the bottomv of the well to apointabove the top. of. said: casing, a packeron said. outer flowtubing: engaging the casing between theperforated. areasfor isolating the stratums from each other with respect to the space-between the casing and the outer flow tubing, said outer flow tubing having a perforated area above-the packerand adjacent the upper perforated area of the casingand being provided with an internal valve seat below said perforated area in the outer flow tubing, an inner flow tubing including a lower section open at' its lower end hung in the lower portion of the outer flow tubing below said. valve seat and extending downwardly to a positionadjacent the lower perforated area in the casing. and an upper vertically morable. section separate fromv the lower section. ex.- tending above the outer flow tubing and having anexternal valve head on its. lower end engageable with said valve seat when said upper section is lowered, said upper section further having packing means on: its; lower portion sealingly engaging the outer flow tubing and. selectively movable to a position above or av position; below the perforated area of the; outer flow tubing by raising or lowering said upper section, whereby communicationmay be established between the inner flow tubing and both stratums or communication may be established between the inner fiowtubing and the lower stratum only whilesimultaneously establishing communication between the outer flow tubing and the upper stratum only.

2. The construction defined in claim I, wherein the upper section of the inner flow tubing has a reduced neck on itsv lower end adapted to enter a restricted passage of the outer fiow tubing below said valve seat when. said valve head is engaged with the latter.

3. In. a dual flowing device for a. well hole which. passes through two vertically spaced oil producing stratums, comprising a. casing lining the well hole from the bottom thereof to the surface of the ground and having upper and lower spaced perforated areas therein for communicating with the stratums, an outer flow tubing. disposed'within and in spaced concentric relation to the casing, a packer surrounding the outer flow tubing and. in sealing engagement with the easing at a location between the perforated areas in the casing, said outer tubing having a fluid inlet below the packer and having a perforated area therein at a position above the packer, an inner flow tubing open at its lower end disposed within and in spaced concentric relation to the outer flow tubing, a packing member surrounding and fixed to the inner flow tubing that sealingly engages the outer fiow tubing, said inner flow tubing being vertically movable in the outer flow tubing to selectively position the packing member above and below the perforated area of the outer flow tubing, whereby communication may be established-between the. inner flow tubing and both stratums; or communication may be established between the inner flow tubing and the lower stratum. only while simultaneously establishing communication between the outer flow tubing and the. upper stratum only.

4. The. construction defined in claimB, wherein heads close the. upper ends; of'thecasing and the flow tubings, in combination with oil delivery file of this patent:

UNITED STATES PATENTS pipes communicating with the upper end por- Number Name Date the tubmgs- 1,871,319 Griswold Aug. 9, 1932 OTIS CRANFILL- 2,274,407 Hammer Feb. 24, 1942 5 2,277,380 Yancey Mar. 24, 1942 REFERENCES CITED 2,403,987 Lewis July 16, 1946 The following references are of record in the 3 39 Bridwen et a1 Sept-h 30) 1947