US2719587A

US2719587A - Well packers

Info

Publication number: US2719587A
Application number: US132588A
Authority: US
Inventors: Cicero C Brown
Original assignee: Individual
Current assignee: Individual
Priority date: 1949-12-12
Filing date: 1949-12-12
Publication date: 1955-10-04
Anticipated expiration: 1972-10-04

Description

Oct. 4, 1955 c. c. BROWN 2,719,587

WELL PACKERS Filed Dec. 12, 1949 5 Sheets-Sheet l C/cero C. Brown I INVENTOR.

ATTORNEYS C. C. BROWN WELL. PACKERS Oct. 4, 1955 5 Sheets-Sheet 2 Filed Dec. 12 1949 C/cero C. Brow/7 INVENTOR.

/4 7 TORNEyJ C. C. BROWN WELL PACKERS Oct. 4, 1955 5 Sheets-Sheet 5 Filed Dec. 12, 1949 C/ ce r0 C. Brown ZNVENTOR.

m MA) A TTOENf KS a 5 5 InPH/ v /rv% L 4/ 7 77 W D w a z a w United States Patent Oflhce 2,719,587 Patented Oct. 4, 1955 invention relates to new and useful improvements in well: packers.

In the usual type ofwell packers, it has been the general practice to employ an annular flexible sealing element constructed ofrubber or the like and to depend upon the weightof thetubing or pipe string to apply an end-wise or longitudinalcompression to the sealing element to expand and maintain the sealing. element in its expanded position. As wells are deepened and packers are set atgreater depths within the well. casing control over the weightapplied tothe packer becomes increasingly diffi-- cult; with the result that the imposition of the weight of the tubing or pipe string. uponthe sealing element. may be excessive and in many instances may actually cause the expanded sealing. elementto deform. or bulge the well casing outwardly; in addition, anexcessive weight imposed upon the packer causesextrusion. or creeping of the sealing element around the retainers whichv normally confine the ends of said element and this extrusion. or fcreeping either alone or in connection with the deformationor bulgingofthe well casing is a major cause of the packer becomingstuck in the well. casing whereby retrieving thereof is diflicult or in some cases impossible.

When the elastic sealing or packing element of a well packer is expanded radially outwardly into sealing engagement with awell casing the fluid between the surface of the element and the wall. of the well casing is substantially displaced and the complete exclusion of fluid from between these surfaces is effected. after. the sealing element has been in its set. position for some time. The-higher temperatures usually present in well bores will assist in this exclusion of fluid between the surfaces of theeler'nent and pipe with the result that the surface of the sealing element will adhere firmly to the wall of the casing Such adherence makes retrieving of the packer diflicillt and in .fact sometimes results in the packer stick. ing? so tightly that it cannot be removed but must be drilled out of said casing.

Some packers such as that illustrated in my co-pending application, Serial No. 116,252, filed September 17, 1949, employ 'pr'essure seal cups whereby the diiferential in' pres sures above and below the packer are utilized for mainmining the packer in place and also whereby said seal cup's' provide the seal with the wall of. the well casing.- Tliistyp'eof packer has proven satisfactory for certain purposes and under certain conditions but it has been found that the use of seal cups alone cannot be depended upon to form an eflicient pack off under all conditions and thus type of packer is not universally applicable for variou'spurposes.

It is one object of the present invention to provide an improved packer which is universally applicable for va'ri'- oiis uses or purposes and for carrying out various well? o erations; for example, the packer may be employed as a production packer in wells producing either from a single zone or from multiple zones, may be utilized as'a' squeeze packer to permit the performance of various squeezeoperations or may function as a testing. tool for pressure testing of the well. casing.

An important object of the invention. is to provide an improved well packer which is readily removable from the well casingin which it is set, whereby the packer may be easily retrieved regardless of the length of time itmay have remained in its set position within the well casing.

An important object of the invention is to provide an improved well packer havingv pressure seal means assoeiat'ed with an anchoring means whereby the dilierential in pressures above and below the packet may be utilized.

to maintain the anchoring means in position within the well casing, said packer also including an annular elastic sealing element which does not depend upon the weight of the tubing alone for maintaining itin\ its. set position whereby the application of excessive weight to the sealing element, which might cause bulging of thepipe, creeping of the material of the sealing element and resultant.

sticking of the packer, is obviated.

A further object is to provide a well packer, of the character described, wherein a mechanical radial displacement of the annular elastic sealing. element is first effected by a coaction with a loweringmandrel or support, after which the sealingelement is moved to final sealing. position by the hydrostatic pressure of the well fluidwitln'n the casing above the packer whereby the application of the weight of the lowering pipe is not depended upon to displace the sealingelement into its final sealing position.

Still another object is to provide a well packer, of' the character described, wherein a'n annular elastic, sealing element has its end's confined bysegmentalretaining. members, which. members are movable radially outwardly by a coaction witha loWering'mandrel or support, ,said upper confining segmental members being engageable with the wall of the wellca'sing to prevent creepingfofthe sealing element around said confining members and to the application of the weight of. the lowering. pipe or tubing to the packer;

A further object of. the invention is to provide a well packer wherein the sealing element and the anchoring means thereof are protected against contact with the fluid within the well casing as the packer is lowered through the casing to prevent detritus and foreign matter which may be present in said fluid from becoming lodged in and around the anchoring means and element and'the'reby interfere with the subsequent setting operation; the isolation of the sealing element and anchoring means also functioning to prevent corrosiondue to direct contact with the fluid within. the well casing after the packer has been set within said casing.

A particular objectlis' to provide an improved well packer wherein. the main sealing element may be moved into and thereafter retained in its set position by the fluid pressure in the well casing above the packer or by a combination of such fluid pressure with a predetermined con.- trolled imposition of weight by the tubing. or pipe string on which the packer is lowered.

A still further object is to provide a well packer. wherein seal cups are employed to pack 0E between the lowering mandrel or pipe and the well casing and wherein the fluid by-pass around the packer during lowering is. through the bore of. the mandrel. or pipe rather than between said mandrel and the packing element of the device, whereby the packing element and anchoring means of the packer is isolated from direct contactwith the fluid within the well casing.

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

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

Figure 1 is an elevation of a well packer, constructed in accordance with the invention and illustrating the same being lowered within a well bore,

Figure 2 is an enlarged view partly in section and partly in elevation of the upper portion of the well packer with the part in position during lowering or raising of the packer within a well casing,

Figure 3 is a continuation of Figure 2 illustrating the lower portion of the packer,

Figure 4 is a view partly in section and partly in elevation of the sealing assembly of the well packer and illustrating the initial radial displacement of the sealing assembly,

Figure 5 is a similar view showing the sealing assembly in its final sealing or set position,

Figure 6 is a horizontal cross-sectional view taken on the line 66 of Figure 2,

Figure 7 is a horizontal cross-sectional view taken on the line 77 of Figure 2,

Figure 8 is a horizontal cross sectional view taken on the line 8-8 of Figure 5,

Figure 9 is a horizontal cross-sectional view taken on the line 9-9 of Figure 5,

Figure 10 is an isometric view of the J-slot which is formed on the mandrel or support of the packer,

Figure 11 is a view of the sealing assembly illustrating a modified form of the retaining or confining end members, v

Figure 12 is a view partly in section and partly in elevation of a modified form of sealing assembly,

Figure 13 is a horizontal cross-sectional view taken on the line l313 of Figure 12,

Figure 14 is a view partly in section and partly in elevation showing still another modification of the invention wherein the annular sealing element below'the upper seal cup is omitted and showing the parts in unseated position, and I Figure 15 is a similar view showing the modified form of packer in its set position.

In the drawings, the numeral 10 designates a well pipe or tubing which is adapted to be lowered through a well casing 11 in the usual manner. An elongate tubular sealing sub or stem 12 is connected'to the lower end of the tubing 10 and this sub has an axial bore 13 extending entirely therethrough, and intermediate its ends the sub is formed with an external beveled or inclined annular shoulder 14. An elongate tubular mandrel or support 15 having a diameter substantially equal to the diameter of the tubing 10 has its upper end threaded into the lower end of the sealing sub or stem 12. The external diameter of the portion 12a of the stem 12 which is below the external shoulder 14 is of a greater diameter than the external diameter of the mandrel 15 and the extreme lower end of the portion 12a is beveled or inclined to provide an annular shoulder 16 at the point of connection between the mandrel and the sub. The tubular mandrel or support is formed with a plurality of fluid openings or slots 17 which are spaced some distance above fluid by-pass openings 18 provided in the lower portion of the mandrel. The lower end of the mandrel may be connected by a coupling 19 with a suitable tail pipe 20 of any desired length.

The mandrel 15 functions as the main support for the well packer and said mandrel has an annular upset portion 21 of enlarged diameter nearer its lower end, with the upper end of this portion forming an annular external shoulder 22 on the mandrel. A J-slot 23 is formed in the upset portion with the vertical leg 23a of the J-slot extending downwardly from the shoulder 22 and the lateral portion 23b ofthe J being disposed slightly below the horizontal center of said upset portion. Although it is preferable that the upset 21 be formed 4 integral with the mandrel 15 it is obvious that it could be formed separately as a sleeve member which may be welded or otherwise secured to the external surface of the mandrel.

An anchoring device or assembly A is adapted to be detachably connected with the mandrel or support and includes a slip carrying cage or sleeve 24 which encircles the mandrel. The cage or sleeve has an inwardly directed lug 25 formed within the lower portion of its bore and said lug 25 is engageable within the J-slot 23 of the mandrel. When said lug is in the lateral portion 23b of said J-slot the mandrel and cage are interconnected and the mandrel may be utilized to raise and lower the cage within the well casing. Rotation of the mandrel to align the lug 25 with the vertical portion 23a of the J-slot will permit the mandrel to be lowered relative to the cage 24.

A lower annular seal member or cup 26 having downwardly directed sealing lips 27 has its upper end molded to a metallic collar or ring 28 which is threaded onto the lower end of the cage or sleeve 24. Suitable reinforcing wires 29 may be molded within the sealing cup 26. The flared downwardly directed lips of the sealing cup are adapted to engage the external surface of the mandrel 15 and of the well casing 11 whereby the sealing cup spans the annular space between the mandrel and the casing to pack olf therebetween.

An annular expander or cone member 30 surrounds the mandrel above the cage or sleeve 24 and the upper portion 30a thereof is cylindrical while its lower portion is formed with a tapered slip-expanding surface 30b. An external annular shoulder 31 is formed intermediate the ends of the expander at the intersection of the lower end of the cylindrical portion 30a and the upper end of the slip-expanding surface 30b. The upper portion of the cylindrical cage 24 encircles the expander 30 and has a flanged retainer collar 32 threaded into its upper end, which collar is of such diameter that it is slidable on the cylindrical portion 30a of the expander 30 above the shoulder 31. Downward movement of the cage or sleeve 24 relative to the expander is limited by the engagement of the lower end of said collar with the shoulder 31 and thus the cage is actually suspended from the expander but said expander may move downwardly relative thereto when the cage is held stationary. The expander or cone member 30 surrounds the mandrel 15 above the upset portion 21 and the lower end of said expander is adapted to engage and be supported upon the annular shoulder 22 formed by said upset portion 21, whereby the expander is suspended from the mandrel but said mandrel may be moved downwardly with respect thereto when the expander is stationary.

The cage or sleeve 24 is formed with a plurality of longitudinal, radially extending slots 33 which extend through the wall of the cage and which are spaced radially therearound. Each slot has its walls tapered inwardly toward the bore of the cage member and longitudinal stop ribs 34 which coact to limit outward movement of elongate slip members 35 are located at the inner end of each slot. Each slip member having external gripping teeth 36 on its outer surface is mounted within one of the slots 33 and is movable in a radial plane relative to the cage 24. The inner surface 37 of each slip memher is tapered complementary to the tapered surface 30b of the expander or cone member 30 and it will be evident that when the expanding surface 30b is raised with respect to the slips, said slips are in a retracted position;'

however, when the expanding surface 30b is moved downwardly relative to the slips, the engagement of the complementary

tapered surfaces

30b and 37 of the expander and slips, respectively, cause a radially outward movement of the slips whereby the gripping teeth of said slips ment O the expander or cone member 30 with respect to the slips during the setting operation the cage 24 carries curved or bowed friction springs 38. The ends. of the friction springs are disposed within slots 39' formed in the external surface of the cage and the lower end of each spring is bolted or otherwise secured to the cage. The curved or bowed portion of the springs 38 has constant frictional engagement with the wall of the well casing.

In setting the slips, the parts are run into the well in the position. shown in Figure 2 with the lug 25 engaged within the lateral portion 23b of the J-slot which limits the upward movement of the cage 24 with respect to the mandrel. At this time the expander or cone member is supported upon the shoulder 22 and the cage 24 is suspended from the shoulder 31, whereby the slips are retracted. When it is desired to set the slips the mandrel is rotated by imparting a rotation to the tubing 10 in a direction which will align the vertical portion 230 of the J-slot with the connecting lug 25, after which a lowering movement of the mandrel with respect to the slip carrying cage 24 is possible. The cage will be held stationary by the frictional engagement of the springs 38 assisted by the frictional engagement of the lower seal cup 26 with the wall of the well casing and as the mandrel moves downwardly the expander or cone member 30 also moves downwardly therewith since it is supported on the external shoulder 22. This causes the tapered surface 30b of the expander to move said slips radially outwardly into gripping contact with'the wall of the well casing. Uponwedging of the tapered surface or cone 30h within the slips, further downward movement of the expander 30 is prevented. Any pressure present be low the seal cup 26 will act against said cup to urge the slips upwardly with respect to the expander or cone mom-- bet-:30 to thereby increase the gripping force of said slips with the well casing.

The;- tubular expander or cone member 30 isadapted to' support an annular sealing assembly B and said sealing' assembly includes a sealing element which is preferablly formed of a plurality of superposed sealing collars 40 which are confined between upper arcuate retaining segments 41 and lower arcuate retaining segments 42; The lower retaining segments 42 are molded to the lowermost sealing collar 40 while the upper retaining segments 41 abut the upper end of the uppermost sealing collars. A plurality of through bolts 43 extend through the lower segments upwardly through the sealing collars 40 and are threaded into the under side of the upper retaining. segments 41. For connecting the lower retainingsegments 42 to the upper end of the expander or cone member 30 a coupling 44 is threaded onto the upper end of the expander and this coupling is provided with a plurality of radially directed slots 45 which are of an inverted T-shape in cross-section whereby a pair of lateral shoulders 46 are formed intermediate the ends of each slot. One of the slots 45 in the coupling 44 is provided for' each through bolt 43 and the head 43a of each bolt is adapted to be inserted within the enlarged lower end of said slot with said head being adapted to abut the shoulders 46. The engagement of the bolt heads within the slots 45 of the coupling 44 will prevent upward displacement of the sealing element from the coupling but at the same time will permit downward and radial outward movement of the through bolts 43 when pressure is applied to the upper end of the sealing element, whereby said bolts will not interfere with the deforming of the sealing element during the setting operation.

The upper retaining segments 41 are molded to the base of an upper seal cup' 47 which is formed with upwardly directed flared sealing lips 48. Suitable reinforcingwires 49' are molded the outer portion of the seal cup 47" and the sealing lips of said cup are in constant engagement with the external surface of the mandrel 15 andthe inner wall of the well casing. Any pressure above 6 the sealing cup 47 is applied to said cup to further spread the sealing lips and to also transmit a downward force through the upper retaining segments to the upper end of the sealing element B.

The upper retaining segments are clearly shown in Figure 8 and said segments are unconnected with each other" except by the material of the seal cup which is attached thereto by molding. When the sealing element B if: its normal unexpanded position (Figure 4) the retaining segments 41 are in abutting relation to each other and are in their so-called inner position. The application of a; radial force outwardly from within the bore 41a formed by the retaining segments will cause said retaining seg ments to move radially outwardly to the position shown in Figure 5 and such movement is limited only by the engagement of the outer peripheral surfaces of the segments 41 with the wall of the well casing. in. a normal position, each segment has a transverse width which is equal to the width of the base ofthe seal cup 47 whereby; normally the bore 41a formed by the segments 41 is of the same diameter as. the lower end oi the bore 47:: orthe seal cup.

The lower retaining segments 42 function in a manner similar to the upper segments and when. the sealing element B is in a. normal unexpanded position the retaining segments 42 are in their inward position and are unconnected with each other exceptfor the material or the lowersealing; collar 40 to whichthey are molded. Upon application of a force radially outwardly from within the bore 42a formed bythe segments 42, said segments-may move radially outwardly toward the wall of the well casing and such outward movement is permitted because the lower ends of the through bolts 43 may move radially within the slots 45 without disengagement of the bolts heads 43a-from the retaining.shoulders-46.-- 1

In the operation of the device the tubular mandrel: or support 15 which. is coupled to the lower end of the well tubing string 10 is connected by means ofthe J-slet 23 and the lug 25 to the slipcarrier and' the parts arein the position shown in Figures 2 and 3 with the slip expander or cone member 30 supported on the shoulder 22 and with the slip cage 24 suspended from the shoulder 31 of the member whereby the slips 35 are in a: retracted position. At this time' the sealing element B- is in a normal undistorted position and the upper eonfining segments 41 as well as. the lower confining seg ments 42 are in a normal inward position. The fluid openings or slots 17 in the mandrel 15 are disposed above the upper sealing cup 47 while the by-pass openings 18 in said mandrel are located below the lower sealing cup 26. The sealing sub or stem 12 is disposed some dis-- tance above the upper seal cup.

As the assembly is lowered downwardly through the well the seal cups 26 and 47 frictionally engage the wall of the well casing and the exterior of. the mandrel andpack off the anchoring mechanism A and sealing assembly B from contact with the fluid which might be present within the bore so" that saidfitiid or any debris or extraneous matter present within the well bore cannot contact said slips and sealing element. It has been foundthat extraneous matter present in the mud or well fluid may become lodged in the anchoring mechanism or in the sealing assembly during loweringand' such extra neous matter may interfere with. subsequent setting. of the packer; with the arrangement shown, this possibility is obviated since the anchoring and sealing assemblies are effectively isolated by the seal cups which functionto seal the annular space between the well casing. and the mandrel. To prevent a pressure lock in the area'- between the seal cups 26 and 47, a small bleed port 15b' is provided in the mandrel. and this port communicates with the area between the seal cups when the mandrel.- is connected to the slip carrier. The port is of such small size that large Particles of'extraneous matter which might be present in the fluid within the wellcasi ng arid.

which may be carried upwardly through the mandrel cannot pass therethrough.

As the packer is lowered through the well casing the fluid therein by-passes upwardly through the tail pipe and through the by-pass openings 18, then upwardly through the mandrel 15 and into the area above the packer through the openings or slots 17 and therefore substantially no resistance by the fluid to lowering is encountered. When the position at which the packer is to be set is reached the well tubing 10 is rotated to impart rotation to the mandrel which moves the vertical portion 23a of the J-slot 23 into alignment with the connection lug 25 of the slip carrier cage and thereafter the mandrel and tubing may be moved downwardly with respect to the assembly. As has been explained the slip carrier 24 is held stationary by the frictional engagement of the springs 38 and lower seal cup 26 with the well casing and as the mandrel is lowered the expander or cone member 30 moves downwardly with respect to the gripping slips whereby said gripping slips are expanded into firm engagement with the wall of the well casing. As soon as the gripping slips engage the casing a further downward movement of the expander 30 is prevented and since the cone member is connected to the lower end of the sealing assembly B furtherdownward movement of said assembly is halted.

Lowering of the tubing 10 is thereafter continued until: the lower enlarged diameter portion 12a of the sealing engaged with both the wall of the well casing and the' exterior of the portion 12a of the mandrel to increase the sealing effectiveness. Continued lowering of the tubing causes the portion 12a to engage the bore 41a formed by the upper retaining segments and to applyanoutward radial force to said segments whereby the outer or peripheral surfaces of the segments are moved into close proximity with the wall of the well casing. Further lowering of the tubing 10 causes entry of the portion 12a into the bore of the elastic packing collars which form the sealing element to apply an outward radial force to said collars and displace their exterior surfaces into close proximity or possibly into contact with the wall of the well casing. After passing through the sealing element the portion 12a coacts with the bore 42a formed by the lower confining segments 42 and will also displace these segments outwardly.

By the time the portion 12 has displaced the retaining segments and sealing element collars radially outwardly the fluid openings or slots 17 in the mandrel have moved below the lower sealing cup 26 and the by-pass between the area below the packer and the area above the packer in the annular space around the mandrel is shut off. Thereafter, the pressure from below acts against the lower seal cup 26 to urge the slip carrier and slips upwardly while the pressure of fluid in the annulus above the packer acts downwardly on the upper seal cup 47 to apply an endwise compression on-the sealing element B and through the sealing element, to apply a downward force on the expander or cone member 30. Therefore, by the time that the portion 12a of the sub 12 has moved to a position opposite the lower retaining segments the pressure in the annulus above the packer has deformed the sealing element B into a tight sealing engagement with the wall of the well casing. In many instances this pressure is sufiicient to maintain the sealing element 40 in an efiicient sealing position'and so long as a dif-' ferential is maintained across the packer the packer will remain in its set position. v Also the downward force on thesealing element is transmitted to the expander to act in a direct opposite to the-force "applied -to the gripping gripping position.

slips and thereby assure maintenance of said slips in a If the pressure in the annulus acting downwardly on the seal cup is excessive the end-wise compression applied to the sealing element 40 may cause the material of said element to extrude or creep upwardly around the upper segments 41 between the exterior surface of said segments ,and the wall of the casing. To prevent such extrusion and creeping and also to utilize some of the weight of the tubing string to assure tight sealing engagement of the'sealing element 40 with the wall of the casing the external shoulder 14 on the sub 12 is provided. This shoulder enters the upper seal cup 47 before the portion 12a has moved completely through the sealing element and since the diameter of the sub above the shoulder 14 is still larger than the portion 12a a furtherradial force is applied to the upper cup 47. As the shoulder 14 moves downwardly through the bore 47a of the upper seal cup said cup is displaced radially outwardly and the shoulder 14 finally comes to rest on the inner upper surface of the metallic 'arcuate retainer segments 41. As the weight is slacked otf on the tubing string to apply weight to the segments, the inclined or-beveled shoulder 14 coacts with the upper inner edge portion of the segments 41 and causes said segments to move further outwardly in a radial direction:until such segments contact the wall of the well casing as shownin Figure 5. In applying the radial forcenecessary to expand the segments 41 some of the tubing-weight will be transmitted to the collars 40 of the-sealing element to apply further. end wise compressionto said element and thereby assure that the outer surface of saiduelement is in tight sealing engagement with the wall :of -1he well casing. After the upper segments have contacted the wall of the well casing further downward .-movement of the tubing is .prevented and no furtherweight can be applied to the sealing element. Thus, it is impossible to apply an excessive weight to the-sealing element-- Theoutward displacement of the arcuate segments 41 into contact with the well casing closes the annular space between said segments and the wall ,of the,.casing and functions to confine the sealing element below; said segments whereby any further application of endwise pressure to the sealing element B by fluid pressure applied through the upper seal cup 47 cannot extrude the element around the retaining segments.

After the packer is set as above described the pressure from below acts on the slip cage or carrier 24 through the lower seal cup while the pressure from above is transmitted through the sealing element to the expander or cone member 30 to urge the same downwardly and thus the pressures are utilized to increase the gripping force of the slips. Because the pressure in the annulus above the packer is confined by the well casing it is obvious that this pressure will never exert sufiicient pressure on the seal member B to cause the same to bulge or deform the pipe because the casing will actually rupture at some point in the annulus before deformation thereof by the sealing element occurs by reason of the fact that nofgreater pressure is applied to the element' than is present in the tubing. The packer may remain set within the well for any length of time and it is evident that flow may be upwardly through the well tubing from a single production zone below the packer or if desired how could be from an upper zone through theannulus above the packer; if 'dual productio'n is being accomplished the dilferential in pressures'between the two'producing zones will maintain the packer in' its locked or set position. It is noted that when in a set position, the 'seal cups 26 and 47 protect the anchoring device and the sealing assembly from contact with the well fluids whereby corrosion of the metallic ports, which might occur when the packer "remains within" the well over, an extended period of time, is obviated. When it is desired to remove the packer it-is only necessary'to lift upwardly on the tubing string to withdraw the sub 12 from within the sealing member B and upper cup 47. As the portion 12a of the sub 12 moves from within the sealing member B the inner radial force which was exerted by this portion is immediately removed and the pressures above and below lower sealing cup 26 are substantially equalized as soon as the slots 17 move above the lower sealing cup; further as the slots 17 move above the cup 26 the pressure below the packer may enter the area between the cups and may act against the underside of the upper cup 47 to reduce the dilierential thereacross. This admitted pressure also tends. to enter the space betweenthe. exterior of thesealing collars. 40 and the well casing. 11? to assist in moving said collars back toward their normal undeformed. positiont' As the resistance to the inward movement of the sealing element is removed and pressure is admitted to the area between the seal cups, any normal elasticity left in the sealing element will immediately act to pull the periphery thereof away from the wall of the well casing,

Raising of the tubing is. continued until the shoulder 22 on the mandrel engages the connecting lug 25 of the cage after which the tubing is rotated to align the vertical portion 23a of the J-slot with said lug so that the shoulder 22 may move upwardly into engagement with the expander or cone member 30. At this time the slots. 17 are above the upper seal cup. and pressures above and below the entire assembly are equalized. In the event the sealing element B has not retracted from the casing wall the shoulder 22' may be utilized to jar upwardly; on, the expander cone member 30' and suchjet is imparted to the sealing assembly. This jar is'longitudinally of the sealing, assembly and will tend to 'break the adherence of' the surface of the sealing collars 40, with the wall of the well casing. After the cone member 30 has been lifted with respect to' the cage 2'4 the log 25 is re-engaged with the lateral portion 2350f the J-slot and thereafter the entire assembly may be removed from the well casing by means of the tubing. the foregoing it will be seen thata well packer is provided which isadapted who looked within the well tubing and to be maintained in its locked position by the action of pressures above and below said packer. The-pressure above the packer is also utilized to apply a. force to the main annular sealing element to distort said element into sealing position and to maintain the same in such, position. Provision is made for imparting an initial radial distortion to the sealing element and a final radial movement to the upper arcuate confining segments of the sealing element toeliminate extrusion of the sealing material under excessive pressure. The arrangement allows a pre-determined amount of weight from the tubing. string to be imparted to the sealing member to assure distortion thereof intosealing position while preventing the application of excessive weight by the tubing string which is likely to cause subsequent sticking oh the packer within the well bore.

The packer may beemployed as: aproduction packer. or said packer may also be used as a squeeze packer, for obviously; after it is in. its set position the fluid openings or slots-157: are disposed below the lower seal cup- 26. Thus, if a. squeeze operation is: to be carried out it is only necessary topump downwardly through the tubing string 101 and to'discharge the material, such: as: cement, outwardly through: the slots 17-; The pressure-developed below the packer by: reason: of: the: squeeze operations will: act against the lower seal. cup: and will merely increase. the: gripping action of. the slips to'prevent upward displacement of the unit. The packer isv also useful in pressure testing operations. a

The upper retaining segments. function: to: confine: the material of. the sealing element. under the usual pres sure conditions which may be. encountered in. well bores. However, under extremely excessive pressures. which might sometimes.- occur above the upper seal cup, it is conceivable that sufiicient pressure might beapplied to the upper end of the sealing element to cause said element to be extruded through the: radial spaces which are formed between the segments when said segments are fully expanded. In order to prevent any possible extrusion through the spaces. between the expanded segments said segments may be constructed as shown in Figure 11. In such event. the retaining segments 41 are provided with interlocking lugs 50 and recesses 51. As is clearly shown in Figure 11, the position of the interengaged lugs and recesses function to span the normal radial spaces between the segments' and definitely prevent extrusion. of the material of the sealing element past said segments. The lower segments 42 may also be provided with interlocking lugs 52 and recesses 53 for the-same purpose.

The particular construction of the sealing assembly B having the upper sealing cup 47 attached thereto is subject to some variation and in: Figure 12 a modified form of structure is shown. In this modification asealing element 60 in the form of an annular sleeve, rather than a plurality of superimposed sealing collars, is provided and the lower end of this sleeve is molded to the' lower arcuate segments 42. The upper seal cup 47' is formed of the same material as the sealing sleeve 60 and a plurality of retaining. segments 141 are molded between the seal cup- 47 and the sealing sleeve 60. Reinforcing wires 61 extend. upwardly from the lower segments 42 entirely through the sleeve, upper segments 141 and intothe cup 47'. The radial. joints 141a between the segmentsll are adapted to be spanned by a segmental ring. 62 which is confined within. adovetailed recess- 63 formed in the exterior surface of the. segments, As. is clearlyshown in Figure 1.2. the joints between the segments of the ring 62 are staggered on offset. with. reference, to the joints 141a between the segments-and thisfunctionsto prevent extrusion: of: the material of the sealing sleeve 60 upwardly through the radial spaces 141a between the segments. The bore. 64- of. the. segments. 141. is formed with an internal recess 65 which receives a seating ring 66 having an upper beveled shoulder 67.. The ring is. provided for the-purposeof coasting. with the external. beveled shoulder 14 of the sub- 12 to effect a radial. displacement of the segments 141 and to' 'also apply aportion of the weight of the tubing. string-to the sealing sleeve 60in the manner hereinbefore. described.

In this form of the invention the through bolts 43 are not requiredand retaining bolts 68 are threaded into the segments 42 and engage within T-shapedslots 69 in a. couplingcollar 70. The heads 68a of thebolts engage shoulders 69a within the: slots and the coupling. 70: is threaded.- onto the upper end of the cone section 30. It is. evident that. the bolts 68 retain the sealingsleeve 6% against upper. displacement from the. expander or cone member 30while permitting. a radial displacement of the sealing: sleeve and the. arcuate end segments- The operation of this form of the invention is identical tothe operation of the form shown in- Figures 1 to 10 hereinbefore described.

In some: instances it may be possible tov omit the sealing: element formed. by the collars 40. in the form shown: in Figures 1-10 or by the sleeve- 60 shown in Figures 12. and 13 and in such event. the structure would be as shown in Figures 14- and 15.. In this form'the tubular mandrel or support 15 is-provided: with the upset'portion 21 hav-- ing the J-slot 23. The. slip carrying cage 24- hasconnection through apin. 25 with the J-slot and said cage has gripping slips'36w similar to the. slips 36 mounted thereinand adapted to coactwith the expander or cone member 30. The seal. cup 126. is molded. to a collar 128 whichis threaded onto the lower end of the slip cage 24 and said cup 126 hasdownwardly directed flared lips 127 which seal between the well casing. andthemandrel. 15.;

The upper end. ofthe expander or cone has a collar 144. threaded. thereon and this-collar has an upper sealing cup 147 molded. thereto. The cup has flared up wardly directed sealing lips 148 which seal off between the casing and the mandrel. The mandrel has connection with a sub 112 and this sub has a diameter which is larger than the bore of the expander or cone member 30 whereby the lower end of the sub 12 is adapted to engage a beveled seat 130 at the upper end of the expander.

In the operation of this form the slip carrier is connected to the mandrel by means of the J-slot and connecting pin as shown in Figure 14 and at this time the expander 30 is supported on the shoulder 22 formedby the upper end of the upset portion.21 with the .slip carrier. The fluid openings or slot 17"in' the mandrel are disposed by the upper cup memberso that a free by-pass of fluid through the mandrel and pastthe seal cups is permitted.

As the device is lowered within the well casing 11 the seal cups 126 and 147 seal between the casing and the mandrel and prevent the fluid within the casing from direct contact with the anchor assembly formed by the slip carrier and its associated parts and by the expander whereby extraneous matter which might be present within the well fluid cannot contact the anchoring assembly.

Setting of the device is accomplished in the manner hereinbefore described with the mandrel being rotated to align the vertical portion of the J-slot with the connecting pin 25 after which lowering of the mandrel with respect to the slip carrier may be effected. Such lowering of the mandrel results in a downward movement of the expander 30 to expand the slips 36a outwardly into gripping position. The mandrel continues its downward movement until the slots or fluid openings 17 are disposed below the lower sealing cup. It will be evident that pressure from below the device acting on the lower seal cup 126 will urge the slips upwardly while the pressure acting on the upper seal cups in a downward direction will urge the expander downwardly and thus the differential of pressures above and below the packer will function to lock the slips more firmly in their engaged position. The pressure seal cups 126 and 147 function to seal off the annular space between the well casing and the mandrel and so long as this pressure does not become excessive the sealing or packing off will be eflicient. It is obvious that in this form of the invention the use of a main sealing element is completely eliminated. Removal of the device from the well is effected in the same manner as the removal of the other forms of the invention hereinbefore described. 1

From the foregoing it will be seen that this invention is one well adapted to attain all of the ends and objects hereinabove set forth, together with other advantages which are obvious and which are inherent to the structure.

It will be understood that certain features and subcombinations are of utility. and may be employed without reference to other features and subcombinations. This is contemplated by and is within the scope of the claims.

As many possible embodiments may be made of the invention without departing from the scope thereof, it is to be understood that all matter herein set forth or shown in the accompanying drawings is to be interpreted as illustrative and not in a limiting sense.

Having described the invention, I claim:

l. -A well packer including, a tubular support adapted to be lowered within a well casing, a gripping slip assembly slidably mounted on the, tubular support, a detachable connection detachably connecting the assembly to the support against relative movement, said gripping slip assembly including an annular slip carrying sleeve and gripping slips carried by the sleeve for gripping the well casing, said assembly also including a lower annular seal member mounted on the sleeve and adapted to seal the annular space between the support and the well casing in which it is lowered, an expander body slidably mounted on the tubular support above the slip assembly, said expander body being adapted to coact with the slips to impart radial movement thereto when the body is moved relative to the slips, retainer means on the support engageable by the expander body for limiting downward movement of the expander body on the support, means on the expander body engageable by the sleeve of the gripping slip assembly to limit downward movement of the assembly on the body, said expander body being movable relative to the slip assembly and to the gripping slips upon movement of the support and expander body in an axial direction with respect to said slip assembly to coact with and expand the gripping slips into gripping contact with the well casing when the slip assembly is disconnected from the support, friction means on said assembly engaging the well casing to hold said slips against axial movement while said support and expander body move axially relative thereto, an upper annular seal member attached to the upper end of the expander body for sealing off the annular space between the support and the well casing, the fluid pressure above and below the respective seal members acting against said members to urge the expander body and gripping slip assembly in opposite axial directions toward each other to increase the gripping engagement of the gripping slips with the well casing, and an annular sealing element surrounding the tubular support and interposed between the upper end of the expander body and the upper seal member and normally in an undistorted position, said sealing element being deformed radially outwardly into sealing contact with the well casing by the fluid pressure acting against the upper seal member.

2. A well packer as set forth in claim 1, wherein the support upon disconnection thereof from the gripping slip assembly and setting of the gripping slips is movable downwardly relative to the annular sealing element, expander body and slip assembly, and means on said support for engaging the bore of the upper seal member and the bore of the sealing element to displace said member and element radially-outwardly, said means being of greater diameter than the bore of the upper seal member and the bore of the. sealing element and being adapted to move interiorly of the upper seal member and the sealing element.

3. A well packer as set forth in claim 1, wherein the support upon disconnection thereof from the gripping slip assembly and setting of the gripping slips is movable downwardly relative to the annular sealing element, expander body and slip assembly, means on said support for engaging the bore of the upper seal member and the bore of the sealing element to displace said member and element radially outwardly, said means being of greater diameter than the bore of the upper seal member and the bore of the sealing element and being adapted to move interiorly of the upper seal member and the sealing element and additional means on said support for engaging the upper portion of the sealing element whereby weight may be imposed on said sealing element through said support to deform the sealing element into fluid excluding sealing engagement with the wall of the well casing.

4. A well packer including, a support adapted to be lowered within a well casing, an anchoring assembly slidably mounted on said support, a detachable connection between the assembly and support for detachably connecting the support and assembly against relative slidable movement, said assembly having expansible pipe gripping means for engaging the well casing to lock the assembly within the well casing including pipe gripping slips and an expander therefor which is movable relative to the slips and which coacts therewith to effect movement of the slips into casing gripping position, friction means on said assembly engaging the well casing to hold said slips against axial movement while said expander may be moved axially relative thereto to move said slips into casing gripping position, an elastic sealing element surrounding the support above the anchoring assembly and supported by said assembly when the latter is. in alocked position in the casing, and an annular packing Cup tached to the upper end of the sealing element and sealing the annular space between the support and well casing, whereby fluid pressure above the cup imparts an axial compression force to the sealing element to deform said element radially into sealing engagement with the well casing.

5. A well packer as set forth in claim 4, together with by-pass means in the support allowing by-pass of fluid from below the sealing element to the area thereabove when the support is connected with the anchoring assembly, detachment of the support from the assemblyv and lowering of the support relative to the assembly closing said by-pass means.

6. A well packer including, a support adapted to be lowered within a well casing, an anchoring assembly slidably mounted on said support, a detachable connection between the assembly and support for detachably connecting the support and assembly including a J-slot and pin, said assembly having expansible gripping means for engaging the well casing to lock the assembly within the well casing including pipe gripping slips and an expander therefor, which is movable relative to the slips and which coacts therewith to effect movement of the slips into casing gripping position, friction means on said assembly engaging the well casing to hold said slips against axial movement while said expander may be moved axially relative thereto to move said slips into casing gripping position, an elastic sealing element surrounding the support above the anchoring assembly and supported by said assembly when the latter is in a locked position in the casing, an annular packing cup attached to the upper end of the sealing element and sealing the annular space between the support and well casing, whereby fluid pressure above the cup imparts an axial compressive force to the sealing element to deform said element radially into sealing engagement with the well casing, and an annular packing cup attached to the lower end of the anchoring assembly below the slips and sealing the space between the support and the well casing, whereby pressure from below the assembly urges the same upwardly to increase the gripping force of the gripping means of said assembly.

7. A well packer as set forth in claim 6, wherein the support has a fluid passage with an opening therein which when the support is connected to the anchoring assembly is disposed above the sealing element and packing cup, whereby circulation from below the sealing element may by-pass through the support to the area thereabove, detachment of the support from the anchoring assembly and locking of said assembly within the casing followed by subsequent lowering of the support relative to the as sembly disposing said fluid opening below the sealing element to shut olf further fluid by-pass around the sealing element.

8. A well packer as set forth in claim 6, together with by-pass means in the support allowing by-pass of fluid from below the sealing element to the area thereabove when the support is connected with the anchoring assembly, detachment of the support from the assembly and lowering of the support relative to the assembly closing said by-pass means.

9. A well packer including, a tubular support, an anchor device slidably mounted on the support and including pipe gripping slips for engaging a well casing, said device having means for moving the slips into gripping position within the well casing, a detachable connection between the device and support and including means on the support for maintaining the expanding means of the device in a position holding the slips retracted, detachment of said connection permitting longitudinal movement of the support relative to the deviceto actuate said expanding means ,to move the slips into gripping position and thereby lock the device within the well casing, friction 1.4 means to hold said. slips against axial movement upon detachment of said connection, said device also including any annular sealing assembly slidably surrounding the support and having its lower end connected to the anchor device whereby the sealing assembly is supported by the anchor device, said sealing assembly comprising an an,- nular elastic packing means, an upper series of radially displaceable retaining segments overlying the packing means and arranged in an annular path, a lower series of. radially displaceable retaining segments underlying the packing means and also arranged in an annular path,

a means on the support having an external diameter larger than the support and movable within the sealing assembly through the bore of the packing means and within the upper and lower series of segments for radially expanding the packing means and retaining segments thereof to move. the packing means outwardly toward the wall of the well casing, and pressure sealing means sealing between the well casing and the support and engageable with the upper end of the packing means, said pressure sealing means being acted uponby the fluid pressure above the sealing assembly for imparting a downward force to the packing means to move the same into sealing engagement with the casing.

10. A well packer including, a tubular support, an anchor device slidably mounted on the support andincluding pipe gripping slips for engaging a well casing, said device having means for moving the slips into gripping position within a well casing, a detachable connection including a J-slot and pin between the device and support, means on the support for maintaining the expanding means of the device in a position holding the slips retracted, detachment of said connection permitting longitudinal movement of the support relative to the device to actuate said expanding means to move the slips into gripping position and thereby lock the device within the well casing, friction means to hold said slips against axial movement upon detachment of said connection, said device also including an annular sealing assembly slidably surrounding the support and having its lower end con nected to the anchor device whereby the sealing assembly is supported by the anchor device, said sealing assembly comprising an annular elastic packing means, an upper series of radially displaceable retaining segments overlying the packing means and arranged in an annular path, a lower series of radially displaceable retaining segments underlying the packing means and also arranged in an annular path, means on the support having an external diameter larger than the support and movable within the sealing assembly through the bore of the packing means and within the upper and lower series of segments for radially expanding the packing means and retaining segments thereof to move the packing means outwardly toward the wall of the well casing, and pressure sealing means sealing between the well casing and the support and engageable with the upper end of the packing means, said pressure sealing means being acted upon by the fluid pressure above the sealing assembly for imparting a downward force to the packing means to move the same into sealing engagement with the casing, said pressure sealing means also transmitting a downward force to the anchor device, and a second pressure sealing means attached to the lower end of the anchor device and acted upon by pressure below the sealing assembly for transmitting an upward force against the anchor device, the opposing forces urging said anchor device into tighter locking position within the well casing.

11. A well packer including, a tubular support, an anchor device slidably mounted on the support and having means for locking the device within a well casing, a detachable connection including a J-slot and pin between the device and support, means on the support for maintaining the locking means of the device retracted, detachment of the connection permitting longitudinal movement 15 of the support relative to the device to actuate said locking means to lock the device within the well casing, friction means to hold said locking means against axial movement upon detachment of said connection, said device also including an annular sealing assembly slidably surrounding the support and having its lower end connected to the anchor device whereby the sealing assembly is supported by the anchor device, said sealing assembly comprising an annular elastic packing means, an upper series of radially displaceable retaining segments overlying the packing means and arranged in an annular'path, a lower series of radially displaceable retaining segments underlying the packing means and also arranged in an annular path, means on the support having an external diameter larger than the support and movable within the sealing assembly through the bore of the packing means and within the upper and lower series of segments for radially expanding the packing means and retaining segments thereof to move the packing means outwardly toward the wall of the well casing, pressure sealing means sealing between the well casing and the support and engageable with the upper end of the packing means, said pressure sealing means being acted upon by the fluid pressure above the sealing assembly for imparting a downward force to the packing means to move the same into sealing engagement with the casing, and an annular enlargement above the enlarged diameter expanding means on the support for engaging the upper portion of the sealing assembly, whereby weight may be imposed on the packing means thereof to apply an axial force thereto to produce radial expansion of the packing means and a radial displacement of the upper confining retaining segments thereof into engagement with the wall of the well casing.

12. A well packer as set forth in claim 11 wherein the upper series of retaining segments engage the wall of the casing to prevent the packing means from extruding upwardly around said retaining segments when the packing means is fully expanded.

References Cited in the file of this patent UNITED STATES PATENTS 2,228,630 Kail Jan. 14, 1941 2,241,532 Barnes May 13, 1941 2,241,561 Spencer May 13, 1941 2,343,076 Otis et al. Feb. 29, 1944 2,368,928 King Feb. 6, 1945 2,382,455 Turechek Aug. 14, 1945 2,416,842 OLeary Mar. 4, 1947 2,578,900 Ragan Dec. 18, 1951 2,585,706 Ware Feb. 12, 1952