Search Images Maps Play YouTube News Gmail Drive More »
Sign in
Screen reader users: click this link for accessible mode. Accessible mode has the same essential features but works better with your reader.

Patents

  1. Advanced Patent Search
Publication numberUS3223169 A
Publication typeGrant
Publication dateDec 14, 1965
Filing dateAug 6, 1962
Priority dateAug 6, 1962
Publication numberUS 3223169 A, US 3223169A, US-A-3223169, US3223169 A, US3223169A
InventorsRoark James T
Original AssigneeOtis Eng Co
Export CitationBiBTeX, EndNote, RefMan
External Links: USPTO, USPTO Assignment, Espacenet
Retrievable well packer
US 3223169 A
Abstract  available in
Images(4)
Previous page
Next page
Claims  available in
Description  (OCR text may contain errors)

Dec. 14, 1965 J. T. ROARK RETRIEVABLE WELL PACKER Filed Aug. 6, 1962 4 Sheets-Sheet 1 INVENTOR James T. Roork t 2M a WW a Dec. 14, 1965 J. 1'. ROARK 3,223,169

RETRIEVABLE WELL PACKER Filed Aug. 6, 1962 4 Sheets-Sheet 2 if INVENTOR Jo ms T. Roork BY 6 W wwz mm Dec. 14, 1965 ROARK 3,223,169

RETRIEVABLE WELL PACKER Filed Aug. 6, 1962 4 Sheets-Sheet 3 INVENTOR James T. Roork BY r Fig. 5 W y/ m Fig.6

United States Patent 3,223,169 RETRIEVAELE WELL PACKER James I. Roarlr, Houston, Tex., assignor to Otis Engineering Corporation, Dallas, Tern, a corporation of Delaware Filed Aug. 6, 1962, Ser. No. 215,035 14 Claims. (Cl. 166-120) This invention relates to well tools and more particularly to well packers.

An object of this invention is to provide a well packer having resilient packing means for sealing the annulus between two telescoped flow conductors, such as a string of tubing and the well casing of a well.

Another object is to provide an annular well packer having expandable locking means for locking the well packer against movement in the well casing in either direction whereby the well packer may withstand either upwardly or downwardly acting forces without being displaced in the well casing after the resilient packing elements have been set.

Still another object is to provide a well packer having a bypass or bypass flow passage disposed inwardly of the resilient packing means and a piston means exposed to the pressure from below the packing elements through the bypass when the packing elements are in expanded position to balance the forces exerted on the packer by the fluid pressure below the packing elements.

Still another object is to provide a well packer having means for closing the bypass while the packer is being lowered in the well.

A further object is to provide a well packer having gripping or locking means movable outwardly into gripping relation with the well casing by the fluid pressure in the well after the packing elements have been moved to expanded position closing the annulus between the tubing string and the well casing.

A still further object is to provide a well packer having means for closing the bypass at its upper end when the packing means is expanded whereby the pressure below the packing elements is effective to move and hold the gripping or locking means in expanded operative position holding the packer against movement in the well casing and also holding the packing means locked in expanded position.

Another object is to provide a well packer having an inner tubular mandrel and an outer tubular member disposed about and spaced from the inner mandrel and providing an annular bypass flow passage past the packing elements carried by the outer tubular member, the outer tubular member having ports communicating with the bypass passage below and above the packing elements and having means for closing one of said ports during movement of the well packer in the well.

Still another object is to provide a well packer wherein the outer tubular member is provided with gripping or locking means movable outwardly into locking and gripping position with the well casing by fluid pressure from below the packing elements of the well packer when the packing elements have been moved to expanded position and the upper port of the outer tubular member has been closed.

A further object is to provide a well packer wherein the outer tubular member has a lower section having means for locking it against downward movement in the well casing and an upper section provided with resilient packing means or elements expandable when the upper section is moved downwardly relative to the lower section and wherein the upper section is provided with gripping and locking means movable outwardly to engage the cats ing when the packing elements have been expanded into 3,223,lfi9 Pa t ented Dec. 14, 1965 sealing engagement with the well casing and the upper port communicating with the bypass flow passage has been closed.

A further object is to provide a Well packer which may be set to close the annulus between the tubing and the casing of the well and thereafter released for movement and setting at another location in the casing.

Additional objects and advantages of the invention will be readily apparent from the reading of the following description of a device constructed in accordance with the invention, and reference to the accompanying drawings thereof, wherein:

FIGURE 1 is a view, partly in elevation and partly in section, taken on line 11 of FIGURE 4 showing an upper portion of a well packer embodying the invention, the operative elements of the packer being in the position assumed thereby during the movement of the well packer into the well;

FIGURE 1A is a view, partly in elevation and partly in section, taken on the line 1A1A of FIGURE 4 showing an intermediate portion of the well packer of FIGURE 1 and being a continuation of FIGURE 1;

FIGURE 2 is a continuation of FIGURE 1-A and is a view partly in elevation and partly in section taken on line 22 of FIGURE 4 showing another intermediate portion of the well packer;

FIGURE 3 is a continuation of FIGURE 2 and is a view partly in elevation and partly in section taken on line 33 of FIGURE 4 showing the lower portion of the well packer;

FIGURE 4 is a top view of the well packer;

FIGURE 5 is a view, partly in elevation and partly in section, of the upper portion of the well packer showing the operative elements thereof in the positions assumed thereby when the packer is in operative position in the well casing closing the annulus between a string of tubing and the well casing;

FIGURE 6 is a continuation of FIGURE 5 and is a view, partly in elevation and partly in section, of an intermediate portion of the well packer;

FIGURE 7 is a continuation of FIGURE 6 and is a view partly in elevation and partly in section of the lower portion of the well packer;

FIGURE 8 is a sectional view taken on line 8-8 of FIGURE 1A;

FIGURE 9 is a sectional view taken on line 99 of FIGURE 3;

FIGURE 10 is a sectional view taken on line 1010 of FIGURE 5;

FIGURE 11 is a view, partly in elevation and partly in section, of the upper portion of a modified form of the well packer;

FIGURE 12 is a continuation of FIGURE 11 and is a view partly in elevation and partly in section of an intermediate portion of the well packer;

FIGURE 13 is a continuation of FIGURE 12 and is a view partly in elevation and partly in section of the lower portion of the well packer; and,

FIGURE 14 is a fragmentary view taken on line 14-14 of FIGURE 13.

The well packer 10 illustrated in FIGURES 1 through 4 of the drawing includes an inner tubular member or main mandrel 11 having an upper sub 12 threaded at its upper end. The upper internally threaded portion 13 of the upper sub is adapted to receive the lower end of a string of tubing to be secured thereto so that the inner mandrel constitutes and forms a section of the string of tubing to which it is connected. The lower end of the mandrel is externally threaded so that the usual tail pipe, not shown, may be secured to the lower end there- 3 of, the tail pipe of course also constituting a section of the string of tubing.

An outer tubular member 16 is telescoped over the main mandrel intermediate its ends and includes a tubular slip expander 17 forming a lower section of the outer tubular member and secured to the upper section 18 of the outer tubular member which includes a packing element mandrel 19, a hold-down body 20 and the cylindrical piston 21. The hold-down body 28 is provided with internal recesses in which are disposed the O-rings 22 and 23 which seal between the hold-down body and the packing element mandrel and the piston, respectively. The lower end of the piston 21 is threaded into the upper end of the hold-down body while the upper end of the packing element mandrel is threaded in the lower end of the hold-down body. The slip expander 17 is held against downward movement relative to the packing element mandrel by an annular cap 24 threaded on the upper end of the slip expander and having an internal flange 25 which extends inwardly of the bore or internal annular surface 26 of the expander to engage the annular upwardly facing shoulder 28 of the external annular flange 29 at the lower end of the packing element mandrel. The lower end of the packing element mandrel may be provided with a plurality of screw driver slots 31 to facilitate its assembly on the hold-down body 20.

The packing element mandrel 19 is of smaller external diameter than the cap 24 and the hold-down body 20 so that the resilient packing elements 33 movably mounted on the packing element mandrel are disposed between the downwardly facing annular shoulder or end surface 38 of the hold-down body and the upper annular surface 39 of the cap 24 whereby downward movement of the hold-down body and packing element mandrel relative to the slip expander causes the packing elements to be compressed between the shoulders 38 and 39 and moved to expanded positions to engage the internal wall surface of the well casing C to seal between the packing element mandrel and the well casing.

The outer tubular member and the main mandrel are spaced to provide an annular bypass flow passage 42 between the lateral lower ports 43 of the slip expander and the upper lateral ports 44 of the piston 21. The main mandrel 11 has external annular recess 45 extending between the annular shoulders 46 and 47 thereof which increases the effective width or cross-sectional area of the annular bypass flow passage. The lower end of the bypass flow passage is defined by the internal annular flange 48 of the slip expander 17 which is provided with an internal annular recess in which is disposed an O- ring or other suitable sealing means 49 for sealing between the main mandrel and the expander.

The lower ports 43, which communicate with the downwardly extending longitudinal slots 50 of the tubular expander 17, are initially closed by a sleeve valve 52 having a pair of external annular recesses in which are disposed the O-rings 53 and 54, or other suitable sealing means, which seal between the valve sleeve and the internal surface 26 of the tubular slip expander above and below the ports 43. The valve sleeve is releasably held in its port closing position by means of the screws 55 threaded in suitable bores 56 of the expander whose inner ends are provided with studs 58 which extend into suitable recesses 59 of the valve sleeve. The studs 58 shear when a downward force of predetermined value is imparted to the valve sleeve when the lower end 60 of the packing element mandrel engages the upper end 61 of the valve sleeve as the upper section of the outer tubular member is moved downwardly with the main mandrel to engage the valve sleeve and move it downwardly in the bore 26 of the slip expander.

The hold-down body 20 may be locked to the well casing C by the locking means or plungers 64 slidably disposed in the lateral bores 65 of the hold-down body which communicate with the annular bypass flow passage 42. The plungers 64 are provided with external annular recesses in which are disposed the O-rings or sealing means 66 which seal between the plungers and the holddown body so that no fluid may escape from the bypass flow passage through the bores in which the plungers are slidably mounted. The outer surfaces of the plungers are provided with upwardly facing teeth or serrations 68 so that when the plungers are moved outwardly by fluid pressure within the bypass flow passage 42 the gripping engagement of the upwardly facing serrations or teeth 68 of the plungers with the inner wall surface of the well casing C prevents upward movement of the holddown body relative to the well casing. Each of the plungers is held in its inner retracted position, illustrated in FIGURE 1, by the leaf spring assemblies 70 and 71 disposed in the longitudinally extending slots 72 of the holddown body which communicate with the bores 65. The free ends of the leaf springs extend into the recesses 73 of the plungers and yieldably hold the plungers in their retracted positions. The ends of the leaf spring assemblies remote from the plungers are rigidly secured to the hold-down body by any suitable means, such as the bolts 75.

The upper end of the piston 21 is provided with an external annular flange 88 disposed above the upper annular shoulder 81 of the internal annular flange 82 at the lower end of the cylinder sleeve 84 whose upper end is threaded on the enlarged lower portion 88 of the upper sub 12. It will be apparent that the upper flanged end of the piston 20 is slidably disposed in an annulus 89 defined by the external surface 90 of the main mandrel above its shoulder 47 and the internal surface 91 of the cylinder sleeve above its upwardly facing shoulder 81. The piston has internal and external annular recesses in which are disposed the O-rings 93 and 94, respectively, which engage the surfaces 90 and 91 of the main mandrel and of the cylinder sleeve, respectively. The cylinder sleeve has a plurality of ports or apertures 96 which communicate the upper end of the annulus 89 with the exterior of the well packer above the packing elements 33. The internal annular flange 82 of the cylinder sleeve has a downwardly opening annular recess 100 in which is disposed at suitable seal assembly 102 for sealing between the cylinder sleeve and the piston. Upward movement of the seal assembly relative to the cylinder sleeve is prevented by the downwardly facing annular shoulder 103 of the cylinder sleeve while downward movement of the seal assembly is limited by the engagement of its lower end with the upwardly facing annular stop surface or shoulder 105 provided by the inwardly extending internal annular flange 106 of the cap 107 threaded on the lower end of the cylinder sleeve. The seal assembly 102, when the main mandrel and the cylinder sleeve are in the lowermost positions relative to the piston and hold-down body, as illustrated in FIG- URE 5, engages the seal surface 118 of enlarged external diameter at the lower end of the piston 21 to seal between the cylinder sleeve and the piston below the upper ports 44 of the outer tubular member.

The slip expander 17 is connected to the slip carrier ring 120 by a pair of bolts 121 whose lower ends are received in upwardly opening threaded bores 122 of the slip carrier ring and whose enlarged heads 124 are slidable in the vertical bores 125 of the slip expander. The bores are provided adjacent their lower ends with the upwardly facing annular shoulders 126 which engage the downwardly facing annular shoulders 127 of the heads of the bolts to limit downward movement of the slip carrier ring 129 relative to the slip expander.

The slip carrier ring may be formed of two semi-circular sections 128 and 129 which are connected together by socket screws 130. The slip carrier ring 120 is provided with recesses 132 having the narrow throats 133 for receiving the T-shaped handles of the slips or gripping means 136. The slips or gripping means 136 have upwardly and outwardly beveled inner surfaces 138 which engage the similarly inclined outer cam surfaces 139 of the slip expander. The slip expander is also provided on opposite sides of the cam surfaces 139 with slots 140 defined by the flanges 141. The slips 136 have lateral tongues or flanges 143 which are received in the grooves or slots 140 and also have lateral slots 144 in which are received the tongues or flanges 141 of the slip expander. It will be apparent to those skilled in the art that the slips and expander are of a type well known and that on downward movement of the slip expander 17 relative to the slips 136, the slips are moved outwardly so that their downwardly facing teeth or serrations 146 engage the internal surface of the well casing in which the packer is disposed. The engagement of the flanges 141 and 143 in the slots 140 and 144, respectively, guides the movement of the slips and together with the engagement of the T-shaped handles 135 in the recesses 132 of the slip carrier rings prevents separation of the slips from the packer.

A bow spring assembly or restraining means 150 mounted on the lower end portion of the main mandrel 11 includes a spring sleeve 152 slidably disposed on the main mandrel and provided at its upper enlarged end portion with an external recess 154 in which is received the inner annular flange 155 of the slip carrier ring 120. The upper external flange 156 of the spring sleeve 152 formed by the recess 154 is in turn received in the internal annular recess 158 of the slip carrier ring. It will be apparent that the engagement of the flanges 155 and 156 of the spring sleeve and the slip carrier ring, respectively, prevents longitudinal movement of the spring sleeve relative to the slip carrier ring 120.

The spring sleeve has an upper external flange 160 provided with a plurality of outwardly opening longitudinally extending recesses 162 in which are received the upper flat portions 163 of the bow springs 165 which are rigidly secured to the spring sleeve by suitable screws 166 which extend into suitable threaded bores of the spring sleeve. The spring sleeve also has an intermediate external annular flange 168 provided with a plurality of outwardly opening longitudinally extending recesses 169 in which are received the flat lower free end portions 170 of the bow springs whose flat inner surfaces 171 slidably engage the flat surfaces 172 of the spring sleeve. A retainer ring 173 disposed in an annular recess of the flange extends about the flange 168 and closes the recesses 169 to prevent outward displacement of the lower free ends of the bow springs.

Movement of the spring sleeve 152 relative to the main mandrel is controlled by a plurality of guide members 175, which may be in the form of screws threaded in suitable bores 176 of the main mandrel whose heads or outer portions extend outwardly into the inverted .T-shaped slots 180 of the spring sleeve.

The short longitudinal portion 181 of each I slot 180 is defined by the upper downwardly facing arcuate surface or shoulder 182 and the lower upwardly facing arcuate shoulder 183. When the well packer is moved into the well casing, the bow springs of course engage the internal wall surface of the well casing and prevent rotational movement of the spring sleeve and also act as friction or brake means tending to hold the spring sleeve against downward movement in the well casing. As a result downward movement of the mandrel when the guide members are in their uppermost positions relative to the spring sleeve engaging the upper shoulders 182, causes the guide members 175 to move downwardly to the lower position in which the guide members engage the shoulder 183 of the spring sleeve whereupon the engagement of the guide members with the spring sleeve causes the spring sleeve to move downwardly with the main mandrel upon further downward movement of the main mandrel.

The longitudinal movement of the main mandrel relative to the spring sleeve is not sufliciently great to cause the expansion of the slips 136 to the degree necessary to cause their engagement with the well casing. When it is desired to cause the slips 136 to engage the well casing, the desired degree of downward longitudinal movement of the main mandrel, and therefore of the slip expander 17, is accomplished by downward and simultaneously clockwise rotation, as seen from above, of the main mandrel which causes each of the guide members 175 to move downwardly and rotationally through the connection portion 185 of the slot defined by the downwardly facing shoulder 186 and the upwardly facing shoulder 187 and into alignment with the long portion 188 of J slots 180. When the guide members are aligned with the upper ends of the long portion or leg 188 of the J slots, the main mandrel may be moved downwardly relative to the spring sleeve and thus cause the expansion of the slips 136 since the slip expander 17 will also move downwardly due both to the weight of the outer tubular member 16 and also due to the frictional engagement of the lower end of the slip expander with the main mandrel.

In use, the well packer 10 is connected to form a section of a string of tubing by connecting the lower end of a section of tubing to the upper sub 12 and then connecting the usual tail pipe, not shown, to the lower threaded end of the main mandrel. The valve sleeve 52 is now releasably held in a position closing the ports 43 by the studs 58 of the screws 55 and the guide members 175 of the mandrel are in the short leg portions 181 of the J slots of the spring sleeve. The outer tubular member 16 is now held in an upper position relative to the spring sleeve 150 and the slips 136 by the engagement of the annular downwardly facing shoulder 190 of the external flange 80 of the piston 21 with the upwardly facing annular shoulder 81 of the inner flange 82 of the cylinder sleeve 84. As the packer is lowered into the well casing, the bow springs 165, whose inherent span is considerably greater than the inside diameter of the well casing C engage the well casing and are deformed or flattened inwardly, the lower free ends 170 of the bow springs sliding on the surfaces 172 to permit such dis tortion or flattening of the bow springs. The frictional forces between the bow springs and the well casing thus tend to hold the spring sleeve against downward movement in the well casing and as a result, the main mandrel moves downwardly relative to the spring sleeve until its guide members 175 engage the upwardly facing arcuate shoulders 183 of the J slots of the spring sleeve. Downward movement of the main mandrel will thereafter cause simultaneous downward movement of the spring sleeve 152.. As was pointed out above, the small downward movement of the main mandrel relative to the spring sleeve as the guide members move from the position wherein they engage the upper arcuate shoulders 182 of the spring sleeve to the position wherein they engage the lower arcuate shoulder 183 of the spring sleeve does not cause suflicient downward movement of the slip expander relative to the slips 136 to cause them to move outwardly into well casing engaging position. During downward movement of the tubing string in the well, the bypass flow passage 42 is closed by the sleeve valve 52 and therefore no foreign material may flow upwardly into the bypass flow passage during such downward movement of the well packer in the well.

When the string of tubing has been moved to the desired depth within the well, and if the well is filled with drilling mud, the drilling mud may be washed out by pumping water or other liquid into the well downwardly through the string of tubing and upwardly through the annulus between the casing and the tubing. The annulus is then closed at the surface and the string of tubing is lifted slightly to move guide members 175 to the positions wherein the guide members engage the downwardly facing shoulders 182 of the spring sleeve. The

string of tubing is then rotated slightly in a clockwise direction, as seen from above, and is also at the same time lowered. During such movement the guide members 175 move from the position wherein they engage the surface 182 of the J slots to the position wherein they are aligned with the long portions of the slots 180.

As the string of tubing is thus rotated and lowered, and since the spring sleeve now is not forced to move downwardly with the main mandrel, since the guide members 175 may now move downwardly in the long portions 188 of the J slots, the slip expander moves downwardly relative to the slips 136. The outer member now moves downwardly with the main mandrel due to its weight and also due to the frictional engagement of the various seal means of the outer tubular member with the main mandrel and the cylinder sleeve. Downward movement of the slip expander 17 causes the slips 136 to move outwardly to expanded position wherein their serrations 146 engage the internal wall of the well casing. When the slips are held against further outward movement, due to their engagement with the well casing, further downward movement of the slip expander 17 is of course arrested. Downward movement of the upper section 18 of the outer tubular member is also now arrested since the lower end of the lowermost packing element 33 now engages the shoulder 39 of the cap 24 on the upper end of the slip expander. Further downward movement of the main mandrel now causes the main mandrel to move downwardly relative to the outer tubular member and during such movement, the seal assembly 102 moves downwardly below the upper ports 44 of the piston 21 and then engages the sealing surface 118 of the piston below the ports 44 and seals therebetween to prevent any flow of fluids between the piston sleeve and the inner flange 82 of the cylinder sleeve. Fluid may flow into the annular space or chamber 192 between the external flange 80 of the piston and the internal flange 82 of the cylinder sleeve as the volume thereof expands due to the downward movement of the flange 82 below the ports 44 since the external diameter of the sleeve of the piston above the seal surface 118 is sufliciently small to permit such flow of fluids as a vacuum condition tends to arise in such chamber as its volume increases until the seal assembly moves below the ports 44 and the chamber 192 is placed in communication with the upper end of the bypass fiow passage. The ports 44 have beveled shoulders 193 in order to prevent any tearing of the resilient seals of the seal assembly 102 which might occur if the shoulders of the .ports did not have such beveled shoulders and the seals had to move past abrupt shoulders.

Once the shoulders 195 and 196 of the cylinder sleeve and the hold-down body are engaged, further downward movement of the main mandrel now causes downward movement of the hold-down body and, since the slip expander is now held against further downward movement by the engagement of the slips with the well casing, such downward movement of the hold-down body and the packing element mandrel 11 which is secured thereto causes the packing elements to be compressed between the shoulders 39 and 38 of the hold-down body and of the cap 24. Such longitudinal compression of the packing elements causes their expansion and sealing engagement with the internal surfaces of the well casing. The continued downward movement of the mandrel relative to the casing then causes the lower annular end surface or shoulder 61 of the packing ele- .ment mandrel to engage the upper annular end surface or shoulder 60 of the sleeve valve and the downward force imparted thereto causes shearing of the studs 58 of the screws 55 and downward movement of the valve sleeve. As the upper seal element 53 moves downwardly past the ports 43 of the expander sleeve, the ports 43 are opened to the annulus between the packer and the string of tubing and the well casing below the expanded packing elements 33 so that the fluid pressure of the well may now flow into the lower end of the bypass flow passage 42. Such flow of fluid into the bypass flow passage is facilitated by the slots 50 of the expander and by the lateral ports 197 of the packing element mandrel 19 which move into alignment or communication with the ports 43 as the packing elements are moved into fully expanded positions. Since the annulus is closed at the surface, the fluid pressure acting on both the inner and outer sides of the plungers 64 is equal so that the plungers do not tend to move in either direction inwardly or outwardly in the bores and are held in their inner retracted positions. The annulus is now opened at the surface to decrease the pressure in the annulus above the expanded packing elements. The differential in the pressure above and below the expanded packing elements, since the pressure below the expanded packing elements is now greater than the pressure thereabove, acting upwardly through the bypass flow passage 42 now moves the plungers outwardly into engagement with the well casing. The upwardly facing teeth or serrations 68 of the plungers engage the well casing and prevent upward displacement of the hold-down body so that any upwardly acting pressure which might tend to move the outer tubular member upwardly now merely results in further or greater compression and expansion of the packing elements and also a greater increase in the force with which the plungers engage the well casing.

Such pressure differential also applies an upward force to the area of the mandrel between the inner surface thereof and the area sealed by the O-ring 93 of the piston. Such upwardly acting force however is counterbalanced by the downwardly acting force exerted on the cylinder sleeve by the fluid pressure from below the expanded sealing elements communicated to the chamber 192 through the bypass flow passage 42 and the ports 44. Downward movement of the tubing string of course is limited by the engagement of the upper end of the piston with the lower end of the upper sub 12. The fluid pressure acts downwardly on the area of the cylinder sleeve sealed by the O-ring 94 of the piston and the seal assembly 102 and since this area is greater than the area exposed to the fluid pressure tending to move the mandrel, and thus the string of tubing, upwardly, the provision of the piston and the bypass flow passage now provides a means for counterbalancing and overcoming the upward force exerted on the string of tubing by the fluid pressure acting from below the expanded sealing packing elements.

When it is desired to remove the tubing string or to move it either upwardly or downwardly in the well, the annulus is closed at the surface and the tubing string is lifted upwardly in the well casing to cause the guide members to move upwardly in the long portions 182 of the J slots. The main mandrel moving upwardly relative to the outer tubular member which is now held against movement by both the slips 136 and the locking means or plungers 64. When the seal assembly 1412 moves upwardly past the upper ports 44 of the piston, the pressure above and below the still expanded packing elements is equalized since the fluid may flow inwardly and past the packing elements through the bypass flow passage. As soon as the pressure on both sides of the expanded packing elements is equalized, the leaf spring assemblies 70 are effective to move the lock plungers inwardly to retracted position and the resilient packing elements tend to move back towards their retracted positions. As the upward movement of the string of tubing is continued, the shoulder 81 of the internal flange of the cylinder sleeve engages the downwardly facing shoulder of the external flange 3d of the piston 21 and thus moves the hold-down body and the packing element mandrel upwardly. Upward movement of the main mandrel and of the upper section 18 of the outer tubular member causes the upwardly facing shoulder 28 of the packing element mandrel to engage the flange 25 of the cap 24 of the slip expander and thus cause upward movement of the slip expander relative to the slips 136 since the bow springs 165 resist upward movement of the spring sleeve. Such upward movement of the slip expander relative to the slips now causes inward movement of the slips towards their retracted positions. The guide members are now at the upper end of the long portions 188 of the J slots and a counter clockwise rotation is imparted to the string of tubing to cause the guide members to move through the connecting portions 185 of the I slots and into engagement with the downwardly facing arcuate shoulders 182 defining the upper ends of the J slots. The tubing string may now be moved either upwardly or downwardly in the well casing to another position therein, the guide members 175 moving upwardly and downwardly in the short leg or portion 181 of the J slots during such upward or downward movement of the mandrel relative to the spring sleeve whose movement in either direction in the well casing of course is resisted due to the engagement of the bow springs 165 with the well casing. When the packer is located at the desired new location in the well, the above sequence of operation may be repeated to lock and set the packer in the well casing.

It will now be seen that a new and improved well packer has been illustrated and described which includes a main mandrel 11 connectable in a string of tubing to constitute a section thereof which has disposed about it in spaced relation thereto an outer tubular member to provide a bypass flow passage 42 past the packing elements 33 mounted on the outer tubular member.

It will also be seen that the outer tubular member is provided with ports communicating with the bypass flow passage above and below the packing elements and that the lower ports are initially closed by a valve sleeve 52 whereby during downward movement of the packer into the well foreign matter may not flow upwardly into the bypass flow passage.

It will further be seen that the well packer is provided with a locking means, the expander 17 and the slips 136, which limits downward movement of the packer in the well casing and with a locking means, the lock plungers 64, which prevents upward movement of the outer tubular member in the well casing and holds the packing elements 33 in fully expanded position.

It will further be seen that the provision of the cylinder sleeve and the piston causes the fluid pressure from below the expanded packing elements to tend to move the main mandrel 11 and thus the tubing string downwardly since the effective area of the upwardly facing surface of the internal flange 82 of the cylinder sleeve exposed to the fluid pressure from below the expanded packing elements is greater than the effective downwardly facing crosssectional area of the main mandrel exposed to such pressure.

It will further be seen that the well packer may be released from any position in which it is locked in the well casing for removal or for movement to another position wherein it may be again reset.

It will further be seen that there is no danger of the string of tubing and the main mandrel being lifted to open the upper ports 44 since the force of the fluid pressure below the expanded packing elements is utilized to counterbalance and overcome the upwardly acting force exerted by such fluid pressure on the string of tubing and the main mandrel.

The well packer 200 is similar in structure to the well packer illustrated in FIGURES 1 through 10, accordingly elements of the packer 200 have been provided with the same reference numerals, to which the subscript a has been added, as the corresponding elements of the well packer 10.

The piston 21:: of the well packer 200 is initially releasably held in the upper position in the cylinder sleeve 84a illustrated in FIGURE 11 by means of the screws 202 whose studs 201 are received in suitable recesses 204 and the external flange a of the piston. The seal assembly 102a is initially positioned below the upper ports 44a of the outer tubular member 16a so that the upper end of the bypass flow passage 42a is initially closed. The cap 24a of the slip expander 17a is provided with one or more ports 205b which communicate with the bypass flow passage 42a through the ports 197a of the packing element mandrel 19a so that the bypass flow passage is always open to the annulus between the casing and the tubing string below the packing elements 33a. The slip expander 17a is not provided with a seal means, such as the O-ring 68 of the well packer 10, since the lower end of the bypass flow passage is always open below the packing elements 33a to the annulus between the tubing string and the casing.

The control pins or guide members 175a of the mandrel 11a are received in the guide slots 180a of the spring sleeve 152a which have not only the upper short portions 181a of the bow spring assembly or restraining means a which provide the downwardly and upwardly facing shoulders 182a and 183a, respectively, but also have intermediate portions 205 providing similar downwardly and upwardly facing shoulders 206 and 207, respectively. The intermediate slot portions are connected to the long portions or legs 188a of the J slots by a connecting portion 208.

When the packer 200 is to be positioned in a well, the v mandrel 11a thereof is connected to the string of tubing by means of its upper sub 12a and a tail pipe, not shown, is connected to its lower end. The piston 21a is rele-asably secured in the upper position illustrated in FIGURE 11 by means of the screws 202 and the guide members are positioned in the intermediate portions 205 of the slots. As the packer is lowered into the well casing, the bow springs a of course engage the well casing and tend to resist downward movement of the spring assembly or restraining means 150a through the well casing. The guide members a are therefore moved with the main mandrel 110 into engagement with the upwardly facing shoulders 207 and thereupon the whole assembly is moved downwardly in the well casing as the string of tubing is lowered in the well. During such downward movement of the well packer, the upper end of the bypass flow passage 42a is closed so that no foreign matter tends to flow upwardly into the bypass flow passage through the ports 205b and 197a.

When the well packer has been lowered to the desired depth and if the well casing is filled with drilling mud, the annulus between the tubing string and the well casing is opened and water or other suitable liquid is pumped downwardly at the surface through the string of tubing into the Well casing and thence upwardly to the surface through the annulus. The annulus is then closed at the surface and the string of tubing is moved slightly upwardly so that the main mandrel and the guide members 175a are moved upwardly in the intermediate short portions 205 of the J slots to engage the shoulders 206. The string of tubing is then rotated clockwise, as seen from above, and at the same time lowered so that the guide members 175a move downwardly through the connecting portions 208 of the slot into alignment with the long slot 188a. As the string of tubing is lowered, the bow springs 165a hold the spring sleeve, and therefore the slip carrier 120a and the slips 136a, against downward movement in the well casing. The outer tubular member, however, moves downwardly with the main mandrel and the slip expander 17:: moves downwardly relative to the slips 136a causing the slips 136a to move outwardly into engagement with the internal wall surface of the casing whereupon further downward movement of the slip expander 17a is stopped. Since the lower end of the lowermost packing element 330 engages the upper end of the cap 240 the shoulder 39a provided by the cap 24a further downward movement of the upper section 18a of the outer tubular member is stopped. ther downward force applied to the string of tubing now causes the studs 291 which connect the piston 21a to the cylinder sleeve 34a to shear and continued further downward movement of the tubing string and main mandrel 11a then causes the lower shoulder 195a of the cap 107a to engage the upper end or shoulder 196a of the hold-down body 20a so that as the main mandrel continues to move downwardly, the packing elements are compressed between the shoulders 38a and 3% of the hold-down body and of the cap 24a, respectively, and expanded into sealing engagement with the internal surfaces of the well casing. The annulus is now opened at the surface to decrease the pressure in the annulus above the expanded packing elements 33a and the resulting pressure differential across the inner and outer surfaces of the lock plungers 6 m moves the lock plungers outwardly into expanded position wherein they engage the internal wall surface of the well casing and their upwardly facing teeth or serrations 68a prevent any upward movement of the hold-down body relative to the well casing. Since the slip expander 17a is now held against downward movement by the slips 136a, the packing elements are locked in expanded sealing engagement with the well casing.

The chamber 192a is now in communication with the annulus below the expanded packing elements 33a through the ports 2051) and 1%a, the bypass flow passage 42a and the upper ports 44a of the piston so that the pressure of the fluid from below the packing elements acting across the area of the internal flange 82a of the cylinder sleeve tends to force or bias the mandrel, and therefore the string of tubing, downwardly in the well casing and thus counterbalances the upward force exerted on the string of tubing by the fluid pressure acting across the area of the main maindrel between the internal surface of the main mandrel 11a and the Om'ng 93a of the cylinder sleeve.

It will thus be seen that in the well packer 200, as well as in the well packer 10, the high pressure below the expanded packing elements 33a which would otherwise tend to lift the string of tubing and the main mandrel is counterbalanced by the force of the fluid pressure acting on the internal flange of the cylinder sleeve so that there is no danger of the string of tubing being lifted and the bypass being opened.

When it is desired to remove the well packer 200 from the wheel or to move it to another position in the well, the string of tubing is lifted causing the seal assembly 102a to move upwardly past the ports 44a of the piston which are thus opened and the pressure across the expanded packing elements equalized through the bypass flow pasr sage 42a. The force of the leaf spring assemblies 70a is effective to move the lock plungers 64a inwardly to their retracted positions so that the packing elements 33a are free to move resiliently to their retracted inner positions. Further upward movement of the string of tubing and the main mandrel now causes the upwardly facing shoulder 81a of the cylinder sleeve to engage the downwardly facing shoulder 190a of the external flange of the piston and upward movement of the main mandrel now moves the upper section 18a of the outer tubular member upwardly to permit full decompression and retraction of the packing elements 33a and then the engagement of the upwardly facing shoulder 28a of the packing element mandrel 1911 with the downwardly facing surface of the flange 25a of the cap 24a of the cone 1711. As a result, the slip expander 17a is moved upwardly relative to the slips 136a which are moved inwardly out of engagement with the well casing toward their retracted positions. Such upward movement of the main mandrel is permitted by the movement of the guide members 175a in the long portions 188a of the I slot 180a and above the intermediate portion 205 thereof. As the main mandrel is moved upwardly, its guide members move through the upper connecting portions 186a of the I slots, the tubing being rotated slightly in a counter-clockwise direction, as seen from 'Furabove, to permit such movement of the guide members into engagement with the downwardly facing arcuate shoulders 182a of the spring sleeve. Further upward movement of the string of tubing will now move the whole well packer upwardly through the well casing.

The well packer may now be removed from the well or may be moved to another location in the well wherein it may be reset by again rotating the string of tubing in a clockwise direction while the string of tubing is being lowered to cause the guide members a to again move through the connecting portions 18% of the slot into the long longitudinal portions 183a of the J slots to again cause the slips 136a to be expanded, the upper ports closed by the movement of the sealing assembly 102a below the ports 44a of the piston, the packing elements 33a to be compressed and expanded and the lock plungers 64a into engagement with the internal wall surfaces of the well casing upon the creation of a pressure differential thereacross by the relieving of the pressure in the annulus between the string of tubing and the well casing at the surface of the well.

It will be apparent that, if desired, rather than having the ports 205]) formed in the cap 24a, the slip expander 17a could be identical to the slip expander 17 and provided with a valve sleeve such as the valve sleeve 52 so that during the initial lowering of the well packer into the casing, the bypass flow passage 42a could be closed at both its upper and lower ends.

It will now be seen that a new and improved well packer has been illustrated and described which utilizes the fluid pressure of the well to lock the packer against displacement in the well and to hold the packing elements thereof in expanded sealing engagement with the well casing.

It will further be seen that the well packer is of such construction that the fluid pressure below the expanded sealing elements is employed to balance and overcome the forces exerted by such fluid pressure tending to move the string of tubing upwardly in the well.

It will further be seen that the well packers described and illustrated each include a main mandrel, an outer tubular mandrel disposed in spaced relation about the mandrel to provide an annular bypass flow passage past the resilient packing elements or seal means carried by the outer tubular member, that the outer tubular member is provided with upper and lower ports on opposite ends of the packing elements, and that the main mandrel is provided with such means as the cylinder sleeve and the sealing assemblies carried thereby for selectively closing the upper ports so that a locking means, such as the lock lungers 64 and 64a of the well packers, may be moved into expanded well casing engaging position by the fluid pressure from below the expanded packing elements to anchor the outer tubular member against upward movement in the well casing and to hold the packing elements in expanded sealing engagement with the well casing.

It will further be seen that the means closing the upper ports are movable upwardly when it is desired to move the packer in the well in order to equalize the pressure across the packing elements and across the locking means to facilitate the release of the well packer from the well casing for movement in the well.

The foregoing description of the invention is explanatory only, and changes in the details of the construction illustrated may be made by those skilled in the art, within the scope of the appended claims, without departing from the spirit of the invention.

What is claimed and desired to be secured by Letters Patent is:

1. A well packer for use in a well casing of a well including: an elongate tubular mandrel; an outer tubular member disposed about said mandrel and having upper and lower sections movable longitudinally relative to each other, said mandrel and said lower section having cooperable means for locking said lower section of said outer tubular member against downward movement in a well casing, said upper section of said outer tubular member having resilient seal means disposed thereabout engageable with said lower section and engageable by said upper section and movable into expanded sealing engagement with a well casing upon downward movement of said upper section relative to said lower section, coengageable means on said upper section and said mandrel for moving said upper section downwardly upon downward movement of said mandrel after said lower section has been locked against downward movement in a well casing, said outer tubular member and said mandrel being spaced to provide a bypass flow passage, said outer tubular member having upper and lower lateral ports communicating with said bypass flow passage and opening outwardly of said outer tubular member above and below said seal means; closure means on said outer tubular member initially closing said lower lateral port against entry of flow of fluid therethrough and openable to permit entry of fluid therethrough into said bypass flow passage; means carried by said mandrel for closing said upper port after said seal means have been moved into expanded sealing engagement with the well casing; and expansible casing gripping lock means carried by said outer tubular member and movable outwardly to grip the casing by the force exerted by fluid pressure in said bypass flow passage for holding said upper section against upward movement.

2. A well packer for use in a well casing of a well including: an elongate tubular main mandrel; an outer tubular member disposed about said mandrel and having upper and lower sections movable longitudinally relative to each other, said mandrel and said lower section having cooperable means for locking said lower section of said outer tubular member against downward movement in a well casing, said upper section of said outer tubular member having resilient seal means disposed thereabout engageable with said lower section and engageable by said upper section of said tubular member and movable into expanded sealing engagement with a well casing upon downward movement of said upper section relative to said lower section, coengageable means on said upper section and said mandrel for moving said upper section downwardly upon downward movement of said main mandrel after said lower section has been locked against downward movement in a well casing, said outer tubular member and said main mandrel being spaced to provide a bypass flow passage, said outer tubular member having upper and lower lateral ports communicating with said bypass flow passage and opening outwardly of said outer tubular member above and below said seal means; means carried by said main mandrel for closing said upper port after said seal means have been moved into expanded sealing engagement with the well casing; and expansible casing gripping lock means carried by said outer tubular member and movable outwardly to grip the casing by the force exerted by fluid pressure in said bypass flow passage for holding said upper section against upward movement, said means for closing said upper port providing an upwardly facing shoulder exposed to the fluid pressure in said bypass flow passage when said port is closed thereby for biasing said mandrel downwardly.

3. A well packer for use in a well casing of a well including: an elongate tubular mandrel; an outer tubular member disposed about said mandrel and having upper and lower sections movable longitudinally relative to each other, said mandrel and said lower section having cooperable means for locking said lower section of said outer tubular member against downward movement in a well casing, said upper section of said outer tubular member having resilient seal means disposed thereabout engageable with said lower section and engageable by said upper section and movable into expanded sealing engagement with a well casing upon downward movement of said upper section relative to said lower section, coengageable means on said upper section and said mandrel for moving said upper section downwardly upon downward movement of said mandrel after said lower section has been locked against downward movement in a well casing, said outer tubular member and said mandrel being spaced to provide a bypass flow passage, said outer tubular member having upper and lower ports communicating with said bypass flow passage and opening outwardly of said outer tubular member above and below said seal means; means carried by said mandrel for closing said upper port after said seal means have been moved into expanded sealing engagement with the well casing; casing gripping lock means carried by said outer tubular member and movable outwardly to grip the casing by the force exerted by fluid pressure in said bypass flow passage for holding said upper section of said tubular member against upward movement; and means carried by said outer tubular member closing the lower end of said bypass flow passage and movable to open position upon downward movement of said upper tubular section relative to said lower tubular section.

4. A well packer for use in a well casing of a well including: an elongate tubular mandrel; an outer tubular member disposed about said mandrel and having upper and lower sections movable longitudinally relative to each other, said mandrel and said lower section having cooperable means for locking said lower section of said outer tubular member against downward movement in a well casing, said upper section of said outer tubular member having resilient seal means disposed thereabout engageable with said lower section and engageable by said upper section and movable into expanded sealing engagement with a well casing upon downward move ment of said upper section relative to said lower section, coengageable means on said upper section and said mandrel for moving said upper section downwardly upon downward movement of said mandrel after said lower section has been locked against downward movement in a well casing, said outer tubular member and said mandrel being spaced to provide a bypass flow passage, said outer tubular member having upper and lower ports communicating with said bypass flow passage and opening outwardly of said outer tubular member above and below said seal means; means carried by said mandrel for closing said upper port after said seal means have been moved into expanded sealing engagement with the well casing; casing gripping lock means carried by said upper section of said outer tubular member and movable outwardly to grip the casing by the force exerted by fluid pressure in said bypass flow passage, said means for closing said upper port providing an upwardly facing shoulder exposed to the fluid pressure in said bypass flow passage when said port is closed for biasing said mandrel downwardly; and means carried by said outer tubular member closing the lower end of said bypass flow passage and movable to open position upon downward movement of said upper tubular section relative to said lower tubular section.

5. A well packer including: an elongate tubular mandrel; an outer tubular member disposed about said mandrel; expandable seal means carried by said outer tubular member, said outer tubular member and said mandrel having cooperable means for expanding said seal means into sealing engagement with a well casing and means for locking said outer tubular member against movement in the well casing, said outer tubular member and said mandrel being spaced to provide a bypass flow passage, said tubular member having upper and lower lateral ports communicating with said bypass flow passage and disposed above and below said seal means, said locking means including casing gripping means carried by said tubular member and exposed to pressure within said fluid bypass flow passage and movable outwardly into expanded well casing engaging position by fluid pressure within said bypass flow passage; releasable closure means initially closing said bypass flow passage below said seal l means and movable to open position to open the lower end of said bypass upon movement of said locking and sealing means to locking and sealing position; and port closing means carried by said mandrel for closing said upper port upon longitudinal movement of said mandrel relative to said outer member.

6. A well packer including: an elongate tubular mandrel; an outer tubular member disposed about said mandrel; expandable seal means carried by said outer tubular member, said outer tubular member and said mandrel having cooperable means for expanding said seal means into sealing engagement with a well casing and means for locking said outer tubular member against movement in the well casing, said outer tubular member and said mandrel being spaced to provide a bypass flow passage, said tubular member having upper and lower lateral ports disposed above and below said seal means and communicating with said bypass flow passage said locking means including expansible gripping means carried by said tubular member and exposed to pressure within said fluid bypass flow passage and movable outwardly into expanded well casing engaging position by fluid pressure within said bypass flow passage; releasable closure means initially closing said bypass flow passage below said seal means and movable to open position to open the lower end of said bypass upon movement of said locking and sealing means to locking and sealing position; and port closing means carried by said mandrel for closing said upper port upon longitudinal movement of said mandrel relative to said outer member; said port closing means having means engageable with said cooperable means of said outer tubular member for expanding said seal means upon longitudinal movement of said mandrel relative to said outer member.

7. A well packer includin an elongate tubular mandrel; an outer tubular member disposed about said mandrel and having upper and lower sections mounted on said mandrel for limited longitudinal movement relative to each other, said upper section of said outer tubular member having resilient seal means disposed thereabout engageable with said lower section and engageable by said upper section and movable into expanded sealing engagement with a well casing upon downward movement of said upper section relative to said lower section, said outer tubular member and said mandrel being spaced to provide a bypass flow passage whose upper and lower ends open laterally to communicate with the exterior of said outer tubular member above and below said seal means; cooperable locking means on said mandrel and said lower section for locking said lower section of said outer tubular member against downward movement in said well casing; means carried by said mandrel and cooperable therewith for causing downward movement of said lower section of said outer tubular member relative to said cooperable locking means of said mandrel to lock said lower section against downward movement in said well casing and then permitting longitudinal downward movement of said mandrel and said upper section relative to said lower section to expand said seal means upon predetermined rotational and longitudinal movement of said mandrel relative to said cooperable means on said mandrel; closure means carried by said mandrel for closing said upper end of said passage while said mandrel and said outer tubular member are being lowered to position in said well casing and also after said seal means have been moved into expanded sealing engagement with the well casing; and expansible casing gripping lock means carried by the upper section of said outer tubular member and movable outwardly to grip the casing by the force exerted by fluid pressure in said passage when said upper end of said passage is closed and said seal means is in expanded position.

8. A well packer including: an elongate tubular mandrel; restraining means carried on said mandrel and having resilient means engageable with the well casing for resisting downward movement of said restraining means through a well casing, said mandrel and said restraining means having means for controlling longitudinal and rotational movement of said mandrel relative to said restraining means; an outer tubular member having upper and lower sections mounted on said mandrel for limited longitudinal movement relative to one another; cooperable locking means on said lower section and said restraining means for locking said lower section against downward movement in said well casing upon limited longitudinal and rotational movement of said mandrel relative to said restraining means, said upper section of said outer tubular member being provided with resilient seal means engageable with said lower section and engageable by said upper section and movable into expanded sealing engagement with the well casing upon downward movement of said upper section relative to said lower section; expansible casing gripping lock means carried by said upper section, said outer tubular member and said mandrel providing a bypass flow passage opening laterally to the exterior of said outer tubular member above and below said seal means; and first closure means carried by said mandrel for closing the lower end of said bypass flow passage, and second closure means carried by the mandrel and movable longitudinally with respect to the upper section of the outer tubular member for closing the upper end of said bypass flow passage, and expansible lock means on said upper section of said outer tubular member being expansible to engage said well casing for locking said upper section of said outer tubular member against upward movement in a well casing by fluid pressure in said bypass flow passage when the upper end of said bypass flow passage is closed above said seal means by said second closure means.

9. A well packer including: an elongate tubular mandrel; restraining sleeve means carried on said mandrel and having resilient means engageable with the well casing for resisting downward movement of said restraining sleeve means through a well casing, said mandrel and said restraining sleeve means having means for controlling longitudinal and rotational movement of said mandrel relative to said restraining sleeve means; an outer tubular member having upper and lower sections mounted on said mandrel for limited longitudinal movement relative to one another; cooperable locking means on said lower section and said restraining sleeve means for locking said lower section against movement in said well casing upon limited longitudinal and rotational movement of said mandrel relative to said restraining sleeve means, said upper section of said tubular member being provided with resilient seal means engageable with said lower section and engageable by said upper section and movable into expanded sealing engagement with the well casing upon downward movement of said upper section relative to said lower section; said outer tubular member and said mandrel providing a bypass flow passage opening laterally to the exterior of said outer tubular member above and below said seal means; closure means carried by said mandrel for closing one end of said bypass flow passage; expansible casing gripping lock means carried by the upper section of said outer tubular member and movable into gripping engagement with said well casing for locking said outer tubular member against upward movement in said well casing and operable by fluid pressure in said bypass flow passage when said bypass flow passage is closed above said seal means by said closure means; and means for releasably holding said closure means in position closing the upper end of said bypass flow passage.

10. A well packer including: an elongate tubular mandrel; restraining sleeve means carried on said mandrel and having resilient means engageable with the Well casing for resisting downward movement of said restraining sleeve means through a well casing, said mandrel and said restraining sleeve means having means for controlling longitudinal and rotational movement of said mandrel relative to said restraining sleeve means; an outer tubular member, said outer tubular member having upper and lower sections mounted on said mandrel for limited longitudinal movement relative to one another; cooperable locking means on said lower section and said restraining sleeve means for locking said lower section against downward movement in said well casing upon limited longitudinal and rotational movement of said mandrel relative to said restraining sleeve means, said upper section of said outer tubular member being provided with resilient seal means engageable with said lower section and engageable by said upper section and movable into expanded sealing engagement with the well casing upon downward movement of said upper section relative to said lower section; said outer tubular member and said mandrel providing a bypass flow passage opening at its ends laterally to the exterior of said outer tubular member above and below said seal means; closure means carried by said mandrel for closing one end of said bypass flow passage; expansible casing gripping lock means carried by the upper section of said outer tubular member for locking said outer tubular member against movement in said well casing and movable to expanded gripping position by fluid pressure in said bypass flow passage when said bypass flow passage is closed above said seal means by said closure means; and releasable closure means closing said bypass flow passage below said seal means, said releasable closure means being moved to open said bypass flow passage when said upper section is moved downwardly relatively to said lower section.

11. A well packer including: an elongate tubular mandrel; restraining sleeve means carried on said mandrel and having resilient means engageable with the well casing for resisting downward movement of said restraining sleeve means through a well casing, said mandrel and said restraining sleeve means having means for controlling longitudinal and rotational movement of said mandrel relative to said restraining sleeve means; an outer tubular member, said outer tubular member having upper and lower sections mounted on said mandrel for limited longitudinal movement relative to one another; cooperable locking means on said lower section and said restraining sleeve means for locking said lower section against downward movement in said well casing upon limited longitudinal and rotational movement of said mandrel relative to said restraining sleeve means, said upper section of said outer tubular member being provided with resilient seal means engageable with said lower section and engageable by said upper section and movable into expanded sealing engagement with the well casing upon downward movement of said upper section relative to said lower section; said outer tubular member and said mandrel providing a bypass fiow passage opening laterally at its ends to the exterior of said outer tubular member above and below said seal means; closure means carried by said mandrel for closing one end ot said bypass flow passage; and lock means carried by the upper section of said outer tubular member for locking said outer tubular member against movement in a well casing and movable to expanded gripping position by fluid pressure in said bypass flow passage when said bypass flow passage is closed above said seal means by said closure means, said closure means of said mandrel providing a chamber between said upper section of said mandrel and said closure means, said upper section of said mandrel having thereon piston means disposed in said chamber, said bypass flow passage communicating with said chamber when said closure means closes said bypass flow passage above said seal means to cause fluid pressure from said bypass flow passage to act on said closure means to bias said mandrel downwardly relatively to said outer tubular member.

12. A well packer including: an elongated tubular mandrel; restraining sleeve means carried on said mandrel and having resilient means engageable with the well casing for resisting downward movement of said restraining sleeve means through a well casing, said mandrel and said restraining sleeve means having means for controlling longitudinal and rotational movement of said mandrel relative to said restraining sleeve means; an outer tubular member on said mandrel, said outer tubular member having upper and lower sections mounted on said mandrel for limited longitudinal movement relative to one another; cooperable locking means on said lower section and said restraining sleeve means for locking said lower section against downward movement in said well casing upon limited longitudinal and rotational movement of said mandrel relative to said restraining sleeve means, said upper section of said outer tubular member being provided with resilient seal means engageable with said lower section and engageable by said upper section and movable into expanded sealing engagement with the well casing upon downward movement of said upper section relative to said lower section; said outer tubular member and said mandrel providing a bypass flow passage opening laterally at its ends to the exterior of said outer tubular member above and below said seal means; first closure means carried by said mandrel for closing the upper end of said bypass flow passage, said first closure means being open while the well packer is being lowered into the well tubing; second closure means carried by the lower section of the outer tubular member initially closing the lateral opening at the lower end of the bypass flow passage against flow therethrough and movable to open position upon downward movement of the upper section of said outer tubular member relative to the lower section thereof; said first closure means being moved to position to close the lateral opening at the upper end of the bypass flow passage above said seal means upon downward movement of said mandrel relative to said upper section, said upper section of said outer tubular member having expansible casing grip ping lock means for locking said upper section of said outer tubular member against movement upwardly in a well casing and movable to expanded gripping position by fluid pressure in said bypass flow passage when the lateral opening at the upper end of said bypass flow passage is closed above said seal means by said first closure means.

13. A well packer for use in a well casing and including: an elongate tubular mandrel; an outer tubular member disposed about said mandrel and having sealing means and gripping means thereon movable into sealing and gripping engagement with a well casing; means providing a bypass flow passage between said mandrel and said outer tubular member having openings above and below said sealing means for conducting fluid past said sealing means; means initially closing said bypass flow passage at its lower end and movable to open position upon movement of said sealing means and gripping means of said packer to sealing and gripping positions to open said bypass; means on said mandrel engageable with said means initially closing said bypass passage to move said closing means to open position upon movement of said gripping means to gripping position; and means on said mandrel movable with said mandrel to close the upper end of said bypass flow passage, after said lower end has been opened, to prevent flow of fluid upwardly through the lateral opening at the upper end of said bypass flow passage.

14. A well packer for use in a well casing and including: an elongate tubular mandrel; an outer tubular member disposed about said mandrel and having sealing means and gripping means thereon movable into sealing and gripping engagement with a well casing; means providing a bypass flow passage between said mandrel and said outer tubular member having openings above and below said sealing means for conducting fluid past said sealing means; means initially closing said bypass flow passage at its lower end and movable to open position upon movement of said sealing means and gripping means of said packer to sealing and gripping positions to open said bypass; means carried by said mandrel engageable with said means initially closing said bypass passage to move said closing means to open position upon movement of said gripping means to gripping position; means on said mandrel movable with said mandrel to close the lateral opening at the upper end of said bypass flow passage, after said lower end has been opened, to prevent flow of fluid upwardly through said bypass flow passage and outwardly through the lateral opening at the upper end thereof to the annulus above the sealing means; and

References Cited by the Examiner UNITED STATES PATENTS 11/1961 Clark et al. 166-134 X 2/1962 Nutter 166134 CHARLES E. OCONNELL, Primary Examiner.

Patent Citations
Cited PatentFiling datePublication dateApplicantTitle
US3008523 *Jul 25, 1958Nov 14, 1961Baker Oil Tools IncRetrievable well packer and anchor
US3020959 *Nov 19, 1958Feb 13, 1962Johnston Testers IncWell packers
Referenced by
Citing PatentFiling datePublication dateApplicantTitle
US3283819 *Jan 2, 1964Nov 8, 1966Camco IncWell packer
US3338308 *Aug 10, 1964Aug 29, 1967Otis Eng CoWell packer and anchor therefor
US3339637 *Oct 14, 1965Sep 5, 1967Halliburton CoWell packers
US3394762 *Dec 11, 1964Jul 30, 1968Otis Eng CoWell tools
US3412790 *Dec 16, 1965Nov 26, 1968Cicero C. BrownWell packer and method of manipulating same in a well bore
US3412801 *Nov 8, 1966Nov 26, 1968Schlumberger Technology CorpRetrievable well packer apparatus
US3459261 *Dec 13, 1965Aug 5, 1969Brown Oil ToolsPressure differential expanding means for well packers
US4003434 *Jul 25, 1975Jan 18, 1977Fmc CorporationMethod and apparatus for running, operating, and retrieving subsea well equipment
US4258787 *Jul 11, 1979Mar 31, 1981Baker International CorporationSubterranean well injection apparatus
US4545431 *May 23, 1984Oct 8, 1985Halliburton CompanyWireline set/tubing retrieve packer type bridge plug
US5070941 *Aug 30, 1990Dec 10, 1991Otis Engineering CorporationDownhole force generator
US5261492 *Mar 31, 1992Nov 16, 1993Halliburton CompanyWell casing apparatus and method
US7510016 *May 3, 2005Mar 31, 2009Specialised Petroleum Services Group LimitedPacker
Classifications
U.S. Classification166/120, 166/240, 166/138, 166/129, 166/134
International ClassificationE21B33/1295, E21B33/12
Cooperative ClassificationE21B33/12955
European ClassificationE21B33/1295F