US3163225A - Well packers - Google Patents

Description

Dec. 29, 1964 L. E. PERKINS 3,163,225

WELL PACKERS Filed Feb. 15, 1961 3 Sheets-Sheet 1 Fig 2 INVENTOR Lee E. Perkins Fl 9 ATTORNEYS L. E. PERKINS WELL PACKERS Dec. 29, 1964 3 Sheets-Sheet 2 Filed Feb. 15, 1961 INVENTOR Lee. E. Perkins ATTORNEYS L. E. PERKINS WELL PACKERS Dec. 29, 1964 Filed Feb. 15, 1961 3 Sheets-Shem 3 INVENTOR 6 s n 2 5. a 9r 25 w e A 5 r I \b P E .n O 8 e 4 L s 8 W 5 4 K N x k a A k L Y M v m f M B 7 F m L .hwmw wxfiuvl -1 E! 9 1/111 H 7 21 I 5 m Cl ATTORNEYS United States Patent 3,163,225 WELL PACKERS Lee E. Perkins, Lafayette, La, assignor to Halliburton Qompany, Duncan, (Bkla, a corporation of Delaware Filed Feb. 15, 1961, Ser. No. 89,438 14 Claimsr (ill. 166-123) This invention relates to well packers and more particularly to a packer for sealing the annular space between two telescoped well flow conductors.

In the drilling or reworking of .oil wells, .it is often desirable to seal between one well flow conductor, such as tubing or other pipe which is telescoped in another flow conductor, such as the .well casing. For example, when it is desired to pump cement or other slurry down a well tubing and to force the slurry out of the tubing into the well casing and thence to a formation, it is necessary to close and seal the annular space between the tubing and the well casing and it is desirable to anchor the tubing to the well casing to prevent the fluid pressure of the cement slurryfrom lifting the tubing upwardly in the well. It is also desirable that the well tool permit the flow of fluids through the well tubing while the tubing is being moved longitudinally through the well casing, that it permit closing of the lower end of the tubing whereby the tubing may be subjected to fluid pressure to test for leaks therein, and that it:close or plug the casing after the tubing has been disengaged from the well tool and positioned with its open lower end above the well tool for other fluid circulating operations which take place above the well tool.

Accordingly, an object of the invention is to provide a new and improved well tool for anchoring one fluid conductor to another in which it is telescoped and to seal therebetween.

Another object is to provide a packer connectable to a tubing string and having anchoring and sealing means which are operable upon rotation of the tubing string relative to the well casing to anchor the packer to the well casing and seal therebetween. Y

Still another object is to'provide a packer, of the type described, having a flow passage communicating with the interior of the tubing and with the casing below the sealing means and a valve for closing the flow passage which is biased toward closed position.

Still another object of the invention is to provide a well packer, of the type described, wherein the forces due to fluid pressure within the tubing acting on the valve are counterbalanced and do not tend to move the valve to open position.

A further object is to provide a well packer, of the type described, having means for moving the valve to closed position after the anchoring and sealing means have been actuated to anchor the packer in the well casing whereby an extension of the tubing telescoped in the packer and communicating with the interior of the packer may be closed so that the fluid pressure within the tubing may be raised to test the tubing for leaks prior to the pumping of cement or other slurry into the well casing and thence to an earth formation.

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 vertical sectional view of the upper portions of the well tool or well packer embodying the invention;

FIGURE 2 is a view similar to FIGURE 1, being a continuation thereof, showing the lower portions of the well packer;

"ice

FIGURE 3 is a vertical sectional view showing the well packer connected to the lower end of a well tubing and to the operating means for setting the anchoring and sealing means of the well packer and for actuating the valve thereof in the well casing, as these devices appear during the lowering of the well packer through the well casing;

FIGURE 4 is a view similar to FIGURE 3, being a continuation thereof, showing the lower portions of the well packer;

FIGURE 5 is a vertical sectional view of the upper portions of the well packer showing the well packer as it appears immediately after it has been anchored in the well casing and its sealing means expanded into sealing engagement with the well casing;

FIGURE 6 is a view similar to FIGURE 5, being a continuation thereof, showing the lower portions of the well packer; and,

FIGURE 7 is a vertical sectional view showing the well packer anchored in the well casing and the valve of the packer in an upper closed position for testing the tubing by fiuid pressure.

Referring now to the drawings, the wellpacker 10 includes amandrel 11 having a longitudinal bore orflow passage 12 whose upper end is enlarged at 13 toprovide an upwardly facingannular shoulder 14 which limits downward movement of'an internal seal assembly in the mandrel. The internal seal assembly includes a resilient sealing.element 17 to whose opposite ends are bonded retainer ringslS and 19. Upward movement of the seal assembly through themandrel bore 12 is prevented by a tension sleeve 21disposed in the upper portion of the flow passage whose lower end is threadedly secured, as at 22, to the mandrel.

The tension sleeve is providedwith an internalannular recess 25 which decreases thethickness of an intermediateannular portion 26 of the tension sleeve to provide the tension sleeve with a circumferential area of relatively low mechanical strength so that the tension sleeve wfll sever or part at theportion 26 when an upward force ofpredetermined value is applied to the upper threaded portion 28 of the sleeve.

Atubular valve housing 30 threaded on the lower end of the mandrel has its lower end closed by acap 31 threaded thereon which is held against rotation relative to the valve housing by theset screws 32. The cap has an upwardly opening annular recess in which is disposed i an O-ring 34 or other suitable sealing means for sealing between theupper surface 35 of the cap and the lower annular shoulder orsurface 36 of thevalvehousingj A valve 40 is slidably mounted in the valve housing and is provided at its lower end with an externalannular flange 41 having an upwardly facingannular shoulder 42 which engages the downwardly facingannular shoulder 43 of the valve housing to limit upward movement of the valve in the valve housing. The valve is provided with a longitudinalcentral bore 45 in which are 'received the upper portions of a biasingspring 46 whose upper end engages the internal downwardly facing-stop surface 47 of the valve. The lower end of the spring abuts or engages theuppersurface 35 of the cap. Thespring guide 48 has its lower end threaded in a bore 48a of the cap and extends upwardly through the biasingspring 45 into the downwardlyopening bore 45 of thevalve 40.

Apressure equalizing port 49 of the valve opens upwardly from thecentral bore 45 thereof. The valve housing has a plurality oflateral ports 51 which cornmunicate with an internalannular recess 52 thereof. The valve housing has a pair of internal annular re cesses below therecess 52 which are provided with 0-rings 54 or other suitable sealing means which seal between thevvalve and the housing belowthe lateral ports of the valve housing.

The upper portions of the valve, when the valve is in the upper position illustrated in FIGURE 2, extend into the lower reduced end portion of theflow passage 12 of the mandrel and are engaged by an internalresilient sealmeans 56 disposed in an internal recess. 57

of the mandrel between a pair ofretainer rings 58 and 59. The assembly of the retainer rings and the seal means, which may be bonded to each other to provide a unitary seal, is held against upward movement by theengagement of the upper end of theupper retainer ring 58 with the downwardly facingannular shoulder 60 of the mandrel and downward movement thereof is limited by the engagement of the lower end of the lower re tainer ring with the upwardly facing shoulder d2 of the valve housing. tational movement relative to the mandrel by theset screws 63.

'A packer assembly is disposed about the packer -rnandrel and above the valve housing between atop anchoring assembly 67 and abottom anchoring assembly 68. Thepacker assembly 65 includes a center resilient seal means orpacker 69 disposed between top and bottom shoes '79 and 71 releasably secured against movement relative .to' the mandrel by the shear screws The valve housing is secured against r0;

to prevent any downward movement thereof relative to the mandrel. The slips are-provided with external recesses 198 in which are received a plurality ofresilient split rings 159 which bias the slips inwardly relative to the mandrel and into engagement with the expanderand with the flange 1133 of the,retainer ring 105. The bot-.

'lQGmLSllPS 1% have downwardlyinclined teeth 112 which are adapted to engage the internal surfaces of'a' well casing C, when moved to an expanded position by upward movement of the slips relative to the expander due to the engagement of the beveled cam surfaces of.

the expander and the slips, to anchor the mandrel against downward movement in the well casing.

' Theupper anchoring assembly 67 includes a top wedge orannular expander 115 releasably held against movement relative to the mandrel by ashear screw 116 which extends through a suitable threaded bore of the top wedge into an aligned lateral threaded bore of theman- 71a and 72, respectively, which extend through threaded boresof-the shoes into the suitable threaded lateral bores of the packer mandrel. The shoesare provided with internal annular recesses in which'are disposed the O- rings or "other suitable sealing means 73 which'seal between the shoes and the mandrel;

The packer assembly also includes topand bottom resilient seal elements or packers. 75 and 76, respectively.

Thetop seal element 75 has atbottomannular endsurface 78 which engages the upwardly andinwardly beveled surface-79 of thetop shoe 70; and. an annular top sur- 7 face 80 which is engaged by the inwardlyand downwardlybeveled surface 81 of atop support ring 82. The'lowersealelement 76 has an upperannular surface 84 which engages the downwardly and inwardly beveled surface 85 ofthe bottom shoe 71 and a bottomannular surface 86 which is engaged by the upwardly and inwardlybeveled surface 87 of abottom support ring 88.

Thelower anchoring assembly 68 includes an annular wedge or, expander 90 disposed about the mandrel whose upper end engages the lower end ofthebottom support ring 88. The annular wedge9ll is releasably secured in vided by the internalannular top flange 132 thereof, and 7 whose internalannular flange 135 extends into an external drel. The lower annular end ofthe top wedge engages the top end of thetop support ring 82. Up- Ward movement of thetop wedge 115 relative'to the mandrel is prevented by asplit ring 118 which is disposed in an external'recess'119 of the mandrel. The

split ring has its top surface engaging the downwardly facing annular shoulder. 12%] of the mandrel and its lower surface engaging the upwardly facingshoulder 121 of thetop wedge 115. Thering 118 prevents any accidental upward movement of the wedge relative to the top'slips 123 whose internal downwardly and outwardly beveled internal cam,surfaces 124 engage the upwardly and inwardly beveled outer cam surface of the top Thetop slips 123 have internal annular. transverse recesses .126 in which is receivedfthe external;annular flange 127 of the topslip retainer ring 128. The

wedge" 115.

engagement of theflange 127 of the top slip retainer ringqin therecesses 126 of the slipsprevents undesired downward movement of the top slips relative to the top wedge.

The top slip retainer ring is'releasably held in an upper position relaitvc to the mandrel by a split resilient lock ring 138 whose upper end engages the downwardly facing internalannular shoulder 131 of the retainer ring proannular recess 13d of the mandrel.

''The upper or top slips have external recesses 149 l in which are received a plurality of resilient split rings the position illustrated in FIGURES 2 and 4 to ;the-

action between thebeveled surfaces 93 and 94 of the wedge and the slips, respectively, tending to move the.

teeth 96 of the slipsinto firmer engagement with the mandrel upon any tendency .of the wedge orexpander 90 to move upwardly relative to the'mandrel. V

' The outer downwardly and inwardly beveledannular cam surface 98 of the expander '90'is engaged by the upwardly and outwardly beveled inner cam surfaces 99 of the circumferentially spaced bottom slips 1G0 disposed about the mandrel. The bottom slips haveinternal recesses 102 adjacent their lower ends in which isreceived the externalannular flange 103 of the bottornslip retainer ring 105 threaded on the mandrel above the valve housing, the upper endof the valve housing engaging-the lower end of the'bottom slip retainer ring The internal slips are" 142 which yieldably bias the slips inwardly toward the 'mandrel and into engagement with the top wedge andreleasably hold therecesses 126 of the slips engaged with theflange 127 of the top slip retainer ring It will be apparent that the camming or wedging action between the beveled cam surfaces 124 of the top slips and the outerbeveled cam surface 125 of the top wedge will cause the top slips tomove'outwardly, relative ,to the mandrel upon downward movement of the slips relative to therexpander. The slips have upwardly inclined external teeth which are adapted to engage the in ternal surfaces of a well casing C when the top slips are in expanded positions relative to the mandrel, to anchor the mandrel against upward movement relative to the well casing. I Y

Thewell packer 10 is secured to the lower end of the tubing T by anextension 156 whoseupper section 151 has a reduced top end portion threaded into the lower end of the tubing and a lower end portion provided with external threads'152. A settingsleeve 155 is slidably and rotatably disposed on theupper extension section 151 and hasinternal threads 156 which engage theexternal threads 152 of the upper section. A plurality of circum ferentially spaced drag springs 158 are secured to the settingsleeve 155 by means of the upperannular retainer 159 which provides a plurality of circumferentially spacedrecesses 160 between the setting sleeve and theretainer 159 in which are received the upper ends of the springs 55 158. The lower ends of the springs may be rigidly secured to the setting sleeve by any suitable means, such as welding.

A trip ring orsleeve 162 is threaded on the lower end of the setting sleeve and its lower end is adapted'to be moved down past theflange 132 of the top slip retainer ring to engage thelock ring 130 and expand it outwardly to move theflange 135 thereof out of the externalannular recess 136 of the mandrel so that the slip retainer ring and the slips maybe moved downwardly on the packer mandrel.

Theintermediate section 164 of thetubing extension 150 is threaded into the lower end of thetop section 151 of the tubing extension. An O-ring 165 or other suitable sealing means is disposed in external annular recess of the intermediate tubing extension to seal between the upper section and the intermediate section. The inter mediatesection 164 of the tubing extension has an external annular flange 166 (see'FIG. whose upwardly facingtop shoulder 167 is adapted to engage the lower end of aretainer sleeve 168 threaded into the upper end of thetension sleeve 21. Theretainer sleeve 168 is provided with an externalannular flange 169 on its upper end which engages the'upper end of the mandrel to limit telescoping movement of the retainer sleeve into the tension sleeve. The lower end of the retainer sleeve is spaced from the upwardly facing lower shoulder 174) of the tension sleeve defining the lower end of theinternal recess 25 thereof. The tubing extension is engaged by theinternal seal element 17 which seals between the packer and the tubing extension.

Abottom section 171 of thetubing extension 150 is threaded into the lower end of the intermediate section of the tubing extension and is provided at its upper end with an external annular recess in which is provided an O-ring 172 or other suitable sealing means which seals between the intermediate and bottom sections. The internal bore or flowpasage 173 of thetubing extension 150 is enlarged at its lower end in the bottom section and an internalannular flange 175, spaced below theshoulder 176 at the upper end of the enlarged portion of the bore, provides an upwardly facing downwardly and inwardlybeveled shoulder 178. Thelower shoulder 179 of the flange is beveled inwardly and upwardly so that the lower portion of the bottom section of the tubing extension may expand elastically due to the camming action of theshoulder 17 8 of the tubing extension and the upper shoulder 44a of the flange or connector head 43:: of thevalve 40 as the lower end portion of the bottom section of the tubing extension is forced downwardly over theflange 43a. The lower end portion contracts as theflange 175 moves below theflange 43a so that the upwardly facingshoulder 178 will then engage the shoulder 44]) of the flange 43:: to detachably secure the lower end of the tubing extension to the valve. Since theshoulders 178 and 44b however are beveled upwardly and outwardly, the lower end of the tubing extension will be again expanded by the camming engagement between these shoulders when an upward force imparted to the tubing extension exceeds a predetermined value and permit theflange 175 to move upwardly past theflange 43a of the valve. The lower section of the tubing extension may thus be detached or released from the valve.

The bottom section of the tubing extension is provided with a plurality oflateral ports 182 which communicate with theports 51 of the valve housing when the valve and the tubing extension are in their lowermost positions relative to the packer. mandrel as illustrated in FIGURES 4 and 6. V a

In use, when it is desired to perform such operations as the pumping of cement slurry down through the tubing to the well casing and then through either the lower end of the well casing or through perforations therein to a formation, thewell packer 10 is secured to the lower end of the. tubing 'T by means of the tubing 6 extension in the manner illustrated in FIGURES 3 and 4, the intermediate and bottom sections of the tubing being telescoped into themandrel 11 until the flange of the tubing extension engages theflange 43a at the upper end of the valve 4!) whereupon further longitudinal inward telescoping movement of the sections into the mandrel causes the valve to move downwardly from its upper closed position illustrated in FIG- URE 2 towards its lower open position illustrated in FIGURE 4 until further downward movement of the valve is stopped by its engagement with thetop surface 35 of thecap 31 whereupon the camming engagement of thelower shoulder 179 of theinternal flange 175 of the bottom section with the upper shoulder 44a causes the lower end of the bottom section to expand, due to the resilience of the substance of which the bottom section is formed, and causes theflange 175 to pass downwardly over' theflange 43a of the valve. The engagement of theupper shoulder 178 of theflange 175 with the lower shoulder 44!) of theflange 43a of the valve then releasably secures the tubing extension to the valve. If any upward movement is then imparted to the tubing extension, the valve will be moved therewith towards its upper closed position towards which it is biased by thespring 46. The tubing extension then remains secured to the valve until upward movement of the valve relative to the mandrel is stopped by the engagement of itsshoulder 42 with the downwardly facingshoulder 43 of thewmandrel and an upward force exerted on the tubing tending to move the tubing extension relative to the mandrel and the valve exceeds a predetermined value sufiiciently great to cause the camming engagement betwene theshoulders 17% and 44b to again expand the lower portion of the tubing extension to permit theflange 175 to move upwardly past theflange 43a.

After the bottom tubing extension section has been thus releasably secured to thevalve 40, theretainer sleeve 168 is screwed downwardly into the tension sleeve I by any suitable means as by a wrench which is inserted into the socket in the flange 16% of the retainer sleeve.

'The tubing extension and the valve will then be held in the lower positions relative to the mandrel against the force exerted by thespring 46 due to the engagement of the upwardly facingshoulder 167 of theexternal flange 166 of the intermediate tubing extension section 1164 with the lower end of the retainer sleeve. The shiftingsleeve 155 is now in the upper position on the toptubing extension section 151 with the lower end of thetrip sleeve 162 held above and out of engagement with the lock ring 139, as seen in FIGURE 3. The seal elements of the sealingassembly 65 are now in their retracted positions since \theshoes 67 and 68 and the bottom and top wedges as and 115 are held in the spaced positions relative to one another illustrated in FIGURES 1 through 4.

The well packer and the tubing are then lowered through the. well casing C with the drag springs 15S engaging the internal wall surfaces of the casing until the packer reaches the desired depth or location in the well casing. During such downward movement of the well packer and the tubing, fluids may flow into the icing string through theports 51 of the valve housing,

theports 132 of the bottom section of the tubing extension and theflow passage 173 of the tubing extension thus facilitating suchdownward movement. The tubing is then rotated in a clockwise direction at the surface to cause thetubing extension 150 to rotate relative to the shifting sleeve and the trip sleeve since these 7 sleeves are held against rotation relative to the well casing due to the engagement of the drag springs158 with the well casing. This rotation of the tubing extension relative to the shifting sleeve rotates thethreads 152 with respect to thethreads 156 and causes the shifting sleeve and thetrip sleeve 162 to move downwardly on the upper tubing section until the lower end of the trip-sleeve engages thelock ring 13 to expand it and move its lowerinternal flange 135 out of theexternal recess 136 of themandrel 11. The top slip re- 'tainer ring 128 and the top slips'l23 are now free to move downwardly relative to themandrel 11. and continued rotation of the tubing now causes the top slip retainer rin to move downwardly relative to the mandrel and the top wedge orexpander 115 since the lockring,

once it is moved out of engagement in theexternal recess 136 of the mandrel, engages the upwardly facingshoulder 186 of the top slip retainer ring, as illustrated in FIG- URE 6, and further downward movement of the shiftingsleeve 162 thus torces the top slip retainer ring downwardly. As the top slips 123. move downwardly relative to thetop wedge 115, the. camming engagement 'between the cam surfaces 124 and 125 of the slips and of the expander, respectively, moves the slips outwardly into engagementwith the internal wall surfaces of the well casing whereupon the upwardly inclined:teeth 145 of the top slips dig or bite into the internal wall surfaces of the well casing. ,Further rotation of the tubing now causes upward movement of themandrel 11 movement thereof causes'successive expansion oftheseal elements 75 and 76 and the successive shearing of the shear screws 71a and 72, since the shear screw 71a has a lesser shear strength than the shear screw '72.

When the seal elements are fully expanded, further upward movement of the,bottom support ring 88 is arrested whereupon further upward movement imparted to the mandrel due to the continued rotation of the tubing now causes theshear screw 92 to shear since thewedge 90 can no longer move upwardly with the mandrel.

As'a result, the bottom slips 1% now move upwardly with the mandrel and are caused to move outwardly, due to the camming engagement of their cam surfaces 99 of the slips with the cam surface 8 "of the bottom wedge orexpander 99, until the downwardlyinclined teeth 112 of the slips engage and bite into the internal wall surfaces of the well casing.

The various elements of the well packer are now in the positions illustrated in FIGURES 5 and 6 wherein is now prevented'by theinternal slips 95 whose teeth '96 tend to dig or bite into the mandrel upon any downward movement of the mandrel relative thereto due to the camming engagement'of the cam surfaces 94 thereof with thecam surface 93 of thebottom expander 9 andby the bottom slips 1% which are forced'further outwardly into more intimate tighter engagement with the internal wall surfaces of the well casing upon any downward movement of the bottom expander.

If desired, the cement slurry may now be pumped downwardly through the well tubing T, theflow passage 173 of the tubing extension; thelateral ports 132 of the tubing extension and the lateral portsSl of the valve housing to the bore ofthe well casing and thence throughrth'e open lower end of the well casing, or through perforations provided .in the well casing below the packer, to the formation. The tubing is held anchored'against up- 8 ward movement by the well packer since theshoulder 167 of theflange 166 of the tubing extension engages'the lower end of the retainer sleeve so that, the pressure of the slurry cannotlift the tubing upwardly in the'well casing 'Alternatively, if it is desired prior to any cementing operations to subject the tubing itself to fluid pressure to discover any possible leaks or holes therein, the tubing is eitherfurther rotated or pulled upwardlyuntil a predetermined upward force is exerted on the upper portion of the tension sleeve which is of suflicient force to cause the weakenedannular section 26 thereof to fail or part,

. whereupon upward movement of the tubing extension relative to the packer mandrel may take place. The tubing is then moved upwardly relative to the mandrel until the valve is in the closed position illustrated in FIG- URE 7. Atthis time thelateral ports 182 of the tubing extension are below the topinternal seal element 17 and above the. seal element '56, and the valve is in its upper position wherein theseal element 56 seals between the valve and the mandrel above thelateral ports 51 of the 'valve housing. Any fluid pumped into the tubing at the surface, cannot now 'flow out of the lower end of the tubing extension. There is no tendency for any increased fluid'pressure within thetubing and the mandrel to move the valve downwardly, since the equalizing port49 of the valve transmits'the fluid pressure to the downwardly facing surfaces of the valve so that the fluid forces exerted on the valve tending to move it in opposite directions are equalized or balanced.

If it is found that the tubing has lealr's or holes, the

tubing may be removed upwardly out of the well for repair, the bottom section of thetubing extension releasextension again moves the valve downwardly to fully open position and the lower end of the tubing moves downwardly over theflange 43a. If the. tubing after testing is found not to have any leaks, it is moved downwardly to again move the valve to open position whereupon the cement or other'slurry or fluids may be pumped downwardly through the tubing to the well casing below the packer. g i

When the cementing operationis completed, the tubing may be pulled upwardlyrelative to the well packer, the engagement of the flange of'the bottom section of the tubing extension moving the valve to its upper fully closed position prior to the release of the tubing extension from the valve. The tubing may then be further raised until the lower end of the tubing extension is 10- cated above the well packer, whereupon other fluid cit.-

culating operatonsmay be carried on above the packer without any fluid'flowing downwardly past the packer to a formation since thevalve is now in the upper closed position in which it is held by the-spring 46. The valve will remain closed even;if a great pressure differential exists across the well packer since the forces exerted by pressure of fluids in the flow passage of the mandrel above the valve is equalized across the valve due to the provision of the equalizingport 49.. As a result, even if the formation pressure below the packer is quite low, there will be no loss of the fluids being circulated between the tubing and the well casing above the packer to the forma- The circulation tion due to the opening of the valve. above the packer may beeither downwardly through'the well tubing and the tubing extension and thence upwardly through the annulus or annular passage between the tub fing and the well casing or, reversely, downwardly through the annulus and upwardly through the tubing.

Thewell packerv 10 may be formed of relatively soft substances so that upon the completion of the cementing operations or, any other operations found desirable, the well packer may be drilled out after the tubing has been removed upwardly from the well.

After the tubing has been'repaired, it may again be lowered downwardly into thewell until the'tubing has been illustrated and described which includes a mandrel having anchoring and sealing means disposed thereon for anchoring the mandrel in a well casing and for sealing between the mandrel and the well casing.

It will further be seen that the mandrel is provided with a valve housing or extension which permits flow of fluids through the mandrel past the sealing'means and that the mandrel is provided with a valve which is movable between a lower open position permitting-flow of fluids through the well packer and an upper closed position wherein flow of fluids through the mandrel is prevented.

'It will further be seen that the valve, when in closed position, is not moved toward open position by fluid pressure within the mandrel because the packer and valve have means for equalizing or balancing the forces exerted on the valve by the fluid pressure within the mandrel.

It will further be seen that the fluid pressure in the well casing below the sealing means of the well packer also does not tend to cause movement of the valve when the valve is in closed position, since the forces exerted by such fluid pressure on the valve are equalized or counterbalanced because O-ring or seal means 54 encompass the same area as theseal 56.

It will further be seen that the valve is movable to its lower closed positionby a tubing extension having port means permitting flow of fluids through the tubing and into the'rnandrel whereby fluids may be pumped downwardly through the tubing and to the well casing below the packer when the valve is held in its lower open position by the tubing extension.

It will further be seen that the well packer is provided with seal means for sealing between the tubing extension and the mandrel above the valve whereby the tubing may be fluid pressure tested when the valve is in upper closed position since flow of fluid out of the lower end of the tubing is thus prevented.

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 packer including: a mandrel; anchoring and sealing means carried by said mandrel and movable to expanded positions to anchor the packer in a flow conductor and seal between the mandrel and the flow conductor, said mandrel having a longitudinal flow passage therein closed at its lower end and a port providing communication between the flow passage and the exterior of the mandrel below said anchoring and sealing means; elongate cylindrical valve means in said flow passage of said mandrel for closing said port movable between a lower open position and an upper closed position; internal annular seal means carried in the bore of the mandrel above and below said port means for sealing between the external cylindrical surface of said valve means and said mandrel; said cylindrical means being movable longitudinally in said seal means; means biasing said valve towards said upper closed position, said valve means having means providing fluid communication from the flow passage above said seal means and said valve means to below said seal means whereby fluid pressure in the flow passage of the mandrel above the valve means may be conducted through the valve means to opposite ends thereof above and below the internal seal means in the mandrel so that the forces of the fluid pressure in the flow passage acting on the valve means are equalized and do not tend to move said valve means from said upper closed position to said lower open position; and internal seal means mounted in the longitudinal flow passage of said mandrel spaced longitudinally above the upper seal means adjacent said port means. i

2. A well packer including: a mandrel having external anchoring and sealing means thereon'for positioning said mandrel in anchored sealing position in a well; saidlmandrel having a bore providing .a longitudinal flow passage closed at its lower end and a lateral port below the sealing means providing communication between the flow passage and the exterior of the mandrel below said sealing means; a valve in said flow passage for closing said port, said valve being movable longitudinally in said flow passage from a position closing said lateral port to a position opening said port; means sealing between said valve and said mandrel; connector head means on the upper end of said valve and accessible through the bore of the mandrel for moving said valve longitudinally of said bore; means conducting fluid to opposed surfaces of said valve on opposite sides of said seal means whereby fluid pressures within the bore of the mandrel acting on the valve are balanced when said valve is in closedposition.

3. A well packet of the character set forth in claim 1 and in combination with a tubular member telescoped into the bore of said packer and having means at its lower end engaging the connector head means at the upper end of said valve member for moving said valve member longitudinally in either direction between open and closed positions as said tubular member is moved longitudinally in the bore of said packer.

4. A well packer including: a mandrel having external anchoring and sealing means thereon for lpositioningrsaid mandrel in anchoring Sealing position in a well; said mandrel having a bore providing a longitudinal flow passage closed at its lower end and having a port means disposed laterally of said longitudinal flow passage and communicating with the exterior of the packer below the sealing means and disposed to provide communication between said longitudinal flow passage and the exterior of the mandrel below said sealing means; an elongate cylindrical valve member slidable longitudinally in said flow passage of said tmandrel for closing and opening said port means; internal annular sealing means disposed in the flow passage of the mandrel above and'below said port means and sealing against the exterior cylindrical surface of said valve member when said valve member is in closed position to close off flow through said .port means between the flow passage of the packer and the exterior thereof below the sealing means; said valve member being movable longitudinally downwardly from an upper position in engagement with said sealing means closing said port to a lower position in which the valve. member is out of engagement with the sealing means above the port whereby fluids may flow from the flow passage of thepacker through the port to the exterior of the packer below the external. sealing means thereon; and means conducting fluid to opposed surfaces of said valve member on opposite sides of said seal means in the bore of said flow passage whereby fluid pressure forces within the =longitudinal'flow passage of the'mandrel 'act upon opposite ends of the valve and are balanced when said valve is in closed position so that fluid pressure-does not displace said valvelmember from closed position.

5. A well packer of the character set forth'in claim 4 wherein the valve member is provided with shoulder means at itsupper end; and an elongate tubular member is te-lescoped into the bore of the .packer and has means at its lower end couplingly engaging said shoulder means of said valve member for moving said valve member longitudinally in either direction between open and closed position with respect to said port as'the tubular member is moved longitudinally in the bore of said packer.

6. In combination: a well packer having external anchoring and sealing means thereonlfor positioningit in sealing position in a well; well flow conductor releasably connected to said well packer and extending therefrom to :the surface of the well when said packer is in anchoring sealing position; said packer having a mandrel with a bore providing a longitudinal flow passage closed at its 11 7 lower end and a port means providing a laterally disposed flow passage extending from the longitudinal flow passage of the packer to the exterior of said packer below the external sealing means thereon whereby fluids may flow from the longitudinal flow passage of' the packer to the bore of the .well below the packer; a valve member movable longitudinally in said longitudinal flow passage of said packer for closing said port; seal means in the bore of the packer on longitudinallyopposite sides of said lateral port means sealing between the exterior of said valve and said packer, whereby said valve when in in the flow passage'of. the mandrelfactin g on the valve means are equalized and do not tend to move said valve means from said upper closed position to said lower open position; flow conductor means telescoped in saidflow passage of the mandrel and having a flow passage; cooperable means on said valve means and said 'flow conductor means releasably connecting the lower end of said one longitudinally disposed position engages both said terior thereof through said port, and when in a second seal means and closes said port and prevents flow of fluids I from the longitudinal flow passageof the packer to the ex- I longitudinally disposed position in the bore of the mandrel engages only the seal means below said port and opens said port to passage of fluids therethrough from'the longitudinal flow passage of .the packer to the 'bore of the well therebelow; means conductingfluid to opposite surfaces of the valve on opposite sides of said seal means whereby fluid pressure forces within the longitudinal flow'pa'ssage'of the mandrel acting on the valve are balanced when thevalve is in closed position whereby said well flow conductor may be disconnected trom said packer and fluids may be circulated within the bore of the well above the packer without opening the valve. 7

i 7. The combination of claim 6 and an elongate tubular valve operator member carried by said well flow conduc tor and having means at its lower end releasably connecting it to said valve; said operator member having port means adjacent its lower .end communicating with the flow conductor means to said valve means, said flow conductor means holding said valve means in said lower open said lower open position to said upper closed-position;

and seal means for sealing between the mandrel and said flow conductor means above said valve means above the means providing communication between the flow passage of the flow conductor means and the flow passage of the mandrelwhen said flow conductor is telescoped in said mandrel flow passage. 7 I a 9. A packer including: a mandrel; anchoring and sealing means carried by said mandrel and movable to expanded positions to anchor the packer in a fiow conductor and seal between the mandrel and the flow conductor," said mandrel havingtalongitudinal flow passage and aport providingcommun-ication between the flow passage and the exterior of the mandrel below said anchoring and sealing means; and elongate cylindrical valve means in said flow passagetot said mandrel for closing said port bore of the packer mandrel above the valve; and seal J means in the bore of the packer mandrel engaging said elongate tubular valve operator member above said port means therein for sealing between member and packer mandrel whereby fluid pressure may be applied within the bore of the packer mandrel and throughout the length of the well flow conductor to ascertain the presence of leaks in the well flow conductor or packer, said valve member remaining closed due to the application of fluid pressure forces equally to opposite ends thereof whereby'opening movement of said valve by the fluid pressure within the longitudinal flow passage of the mandrel is prevented. i

' '8, A packer including: a mandrel; anchoringand sealing means carried by said mandrel and movable to extor and seal between the mandrel and the flow conductor, said mandrel having a longitudinal bore providing a flow passage closed at its lower end and a lateral port providing communication between the flow passage and the exmovable betweena lower open *position and an upper closed position; thefiow passage of the mandrel below said valve' means being closed; internal annular seal means mounted in the bore, of the mandrel above and below said port means for sealing between the external cylindrical surface of said valve means and said mandrel; meansbiasing said valve means toward said upper closed position, :said valve means having means providing fluid panded positions to anchor the packer in a flow conducterior of the mandrel below said anchoring and sealing means;elonga te cylindrical valve means in said flow pas sage of said mandrel for closing said port movable between a lower open position and an upper closed position;

,interrial annular seal means disposedtin the bore of said mandrel above and below said port means for sealing between the external cylindrical surface of said valve means and said mandrel, said cylindricalvalve means being movable longitudinally in said seal means between means in said mandrel; means biasing said valve means toward said upper closed position, said valve means hav-' ing means providing fluid communication from the flow communication from the 'flow passage above said seal means and said valve means to the flow passage'of the mandrel below said seal means whereby fluid pressure within the flow passage of the mandrel above the valve means may pass through the valve means to the opposite end thereof below said internal annular seal means in the mandrel so that-the forces of the fluid pressure in the flow passage acting on the valve means are equalized and do not tend to move said valve from said upper closed position to said lower open position; said valve means being movable longitudinally downwardly from said upper closed position to the lower open position in which the cylindrical exterior surface of the valve is moved out of sealing engagement with the seal means in the bore of the mandrel above the port means, whereby the'port means and the flow passage of the mandrel are in fluid communication; and cooperable means on said mandrel and said valve means for limiting both downward and upward movement of 'said valve means in said mandrel.

10. A well packer including: a tubular mandrel closed at its lower end; anchoring means carried by said mandrel for movement to expanded position for engaging a well flow conductor to hold said mandrel against movement passage of the mandrel above said seal means and said valve means to the bore of the mandrel below said seal passage to opposite ends of said cylindrical valve means 7 on opposite sides of said seal means when said valve is in the closed position so that the forcesof the fluid pressure in the flow conductor; sealing means carried by said mandrel and movableto expanded position for sealing belongitudinal position spaced longitudinally from said one position wherein said valve means permits communication between the interior and the exterior of the mandrel through said port means; means yieldably biasing said valve means toward said one position; internal annular seal means carried by the mandrel in the bore thereof above and below said port means and engaging the external cylindrical surface of said valve means when said valve means is in closed position to close oil flow through said port means when said valve means is in said one position; and means providing fluid communication between opposite ends of said valve means whereby fluid pressure within the bore of the mandrel is conducted through the valve means to opposite ends thereof above and below the seal means when said valve means is in said one position closing said port means so that the forces of the fluid pressure in the mandrel exerted on the valve means are counterbalanced and do not tend to move the valve means from closed-to open position when the valve is in closed position.

11. The well packer ofclaim 10 including: internal 7 seal means in said mandrel spaced above said valve means; and an operator member telescopable into said mandrel, said operator member having means thereon for connecting the lower end of the-same with the connector cylindrical valve means for moving said valve means in both directions between said longitudinally spaced extreme longitudinal positions.

13. The well packer ofclaim 10, and an operator member telescopable in said mandrel and having means on its lower end operatively connecting said operator member with the connector means at the upper end of said cylindrical valve means for moving said valve means in both directions between said longitudinally spaced extreme longitudinal positions, said mandrel having internal seal means for sealing between said mandrel and said operator member, said operator member having a flow passage communicating with the interior of said mandrel below 14 said seal means when said operator member is telescoped in said mandrel.

14. A wellpacker including: a mandrel having external anchoring and sealing means; said mandrel'having a longitudinal flow passage closed at its lower end and a lateral port providing communication between said flow passage and the exterior of the mandrel; an elongate cylindrical valve in said flow passage for closing said port, said valve being movable longitudinally in said flow passage between a position' closing said lateral port and a position opening said port; internal annular seal means in said flow passage and engaging the exterior surface of said cylindrical valve for sealing therebetween when said valve is in said port closing position; said valve having a longitudinal flow passage provided therein for conducting fluid pressure from the flow passage of the mandrel above said valve to the flow passage of the mandrel below the valve whereby fluid pressure conducted through the valve acts on opposed areas thereof above and below said seal means so that the forces of fluid pressure in said flow passage acting on said valve are balanced when the valve is in closed position and have no tendency to move said valve to open position; and connector head means on the upper end of said cylindrical valve accessible through the flow passage of the mandrel for moving said valve longitudinally in said flow passage.

References Cited by the Examiner UNITED STATES PATENTS CHARLES E. OCONNELL, Primary Examiner.

BENJAMIN BENDETT, Examiner.

UNITED STATES PATENT OQFFICE CERTIFICATE OF CORRECTION Patent No. 3,163,225 December 29, 1964 Lee E. Perkins It is hereby certified that error appears in the above numbered patent requiring correction and that the said Letters Patent should read as corrected below.

Column 6,line 32, for "betwene" read betweencolumn 10,line 19, for the claim reference numeral "1" read 2 Signed and sealed this 20th day of July 1965,

(SEAL) Attest:

ERNEST W. SWIDER EDWARD J. BRENNER Attesting Officer Commissioner of Patents

Claims (1)

1. A PACKER INCLUDING: A MANDREL; ANCHORING AND SEALING MEANS CARRIED BY SAID MANDREL AND MOVABLE TO EXPANDED POSITIONS TO ANCHOR THE PACKER IN A FLOW CONDUCTOR AND SEAL BETWEEN THE MANDREL AND THE FLOW CONDUCTOR, SAID MANDREL HAVING A LONGITUDINAL FLOW PASSAGE THEREIN CLOSED AT ITS LOWER END AND A PORT PROVIDING COMMUNICATION BETWEN THE FLOW PASSAGE AND THE EXTERIOR OF THE MANDREL BELOW SAID ANCHORING AND SEALING MEANS; ELONGATE CYLINDRICAL VALVE MEANS IN SAID FLOW PASSAGE OF SAID MANDREL FOR CLOSING SAID PORT MOVABLE BETWEEN A LOWER OPEN POSITION AND AN UPPER CLOSED POSITION; INTERNAL ANNULAR SEAL MEANS CARRIED IN THE BORE OF THE MANDREL ABOVE AND BELOW SAID PORT MEANS FOR SEALING BETWEEN THE EXTERNAL CYLINDRICAL SURFACE OF SAID VALVE MEANS AND SAID MANDREL; SAID CYLINDRICAL MEANS BEING MOVABLE LONGITUDINALLY IN SAID SEAL MEANS; MEANS BIASING SAID VALVE TOWARDS SAID UPPER CLOSED POSITION, SAID VALVE MEANS HAVING MEANS PROVIDING FLUID COMMUNICATION FROM THE FLOW PASSAGE ABOVE SAID SEAL MEANS AND SAID VALVE MEANS TO BELOW SAID SEAL MEANS WHEREBY FLUID PRESSURE IN THE FLOW PASSAGE OF THE MANDREL ABOVE THE VALVE MEANS MAY BE CONDUCTED THROUGH THE VALVE MEANS TO OPPOSITE END THEREOF ABOVE AND BELOW THE INTERNAL SEAL MEANS IN THE MANDREL SO THAT THE FORCES OF THE FLUID PRESSURE IN THE FLOW PASSAGE ACTING ON THE VALVE MEANS ARE EQUALIZED AND DO NOT TEND TO MOVE SAID VALVE MEANS FROM SAID UPPER CLOSED POSITION TO SAID LOWER OPEN POSITION; AND INTERNAL SEAL MEANS MOUNTED IN THE LONGITUDINAL FLOW PASSAGE OF SAID MANDREL SPACED LONGITUDINALLY ABOVE THE UPPER SEAL MEANS ADJACENT SAID PORT MEANS.

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