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.


  1. Advanced Patent Search
Publication numberUS2715444 A
Publication typeGrant
Publication dateAug 16, 1955
Filing dateMar 17, 1950
Priority dateMar 17, 1950
Publication numberUS 2715444 A, US 2715444A, US-A-2715444, US2715444 A, US2715444A
InventorsFewel Kenneth J
Original AssigneeHalliburton Oil Well Cementing
Export CitationBiBTeX, EndNote, RefMan
External Links: USPTO, USPTO Assignment, Espacenet
Hydraulic packers
US 2715444 A
Abstract  available in
Previous page
Next page
Claims  available in
Description  (OCR text may contain errors)

Aug. 16, 1955 K. .1. FEWEL.

HYDRAULIC PACKERS 2 Sheets-Sheet l Filed March l?, 1950 'lll lidl'l i FIG 3 FIG 2 l. RE O W T E N F E V J m H T E N N F. K

ATTORNEY Allg. 16, 1955 K. J, FEWEL HYDRAULIC PACKERS llnited States Patent O nvnnnnrrc racrrnns Kenneth 5. Fewel, Burman, iila., assigner to Halliburton @il Well Ceinenting Cnmpany, Duncan, Okla.

Application March 17, 1950, Serial No. 150,313

1 Claim. (Cl. 16d-4.87)

The provision of packers for sealing tubing in a well :Et

bore is common and the art may be said to be well developed. Typical examples of prior patents showing packers suitable for use in squeeze cementing of oil wells are Halliburton 2,235,318 issued March 18, 1941; Stoddard 2,274,940 issued March 3, 1942, and Verheul et al. 1"

2,341,832 issued February l5, 1944.

However, the prior art still leaves something to be desired in the provision of means for preventing the ow of duid under certain conditions. Swab cups, such as proposed by Stoddard and Verheul et al. are often not satisfactory because they cannot be expanded to maintain a seal under high pressure. On the other hand, with the arrangement of the Halliburton patent cited, the inflated packers do not maintain their seals with the casing if the pressure goes off. The prime purpose of the present invention is to provide a packer assembly wherein packers expanded by iiuid pressure and slips set by uid pressure may be held expanded and set even though the pressure is released.

Accordingly, it is an object of the present invention to provide a novel arrangement for setting and securing tubing packers in casing in a borehole in such a way as to seal the bore against pressure and at the same time prevent the movement of fluid either upwardly or downwardly in the annulus between the tubing and casing.

Another object of this invention is to provide an arrangement for sealing a conduit in a well bore by the use of a packer which can be collapsed when desired so as to allow the flow of fluid past it and thus eliminate wear on the packer, such as is experienced when rubber cups like those of the Stoddard patent cited above are used.

A further object of the invention is to provide a hydraulic packer having an arrangement for securing it in the well with sealed-in uid pressure, the arrangement being such that upon an increase in pressure, either above or below the packer, it will be secured more iirmly in the well.

A still further object of the invention is to provide two packers mounted on a common mandrel and arranged to seal the end ot' a conduit in a well bore and to be set and sealed in set portion by hydraulic means, such packers being compressed rather than inflated, upon expansion in order to provide a more substantial seal than has been obtained heretofore.

Still another object of the invention is to provide a novel safety joint structure for use with a squeeze packer.

These and other objects of the invention are accomplished by the hereinafter described embodiment shown in the accompanying drawings, wherein- Fig. 1 is a longitudinal sectional view of apparatus constructed in accordance with the principles of the in- ICC vention, the parts being shown in the positions they occupy when the apparatus is being lowered into the well;

Fig. 2 is a longitudinal sectional View of a portion of the apparatus shown in Fig. 1, with the parts being shown in the position they occupy when the packers are set;

Fig. 3 is a longitudinal sectional view similar to that of Fig. 2, but showing the packers sealed in a set position, the various parts shown being in the positions they occupy during the squeeze cementing operation on the well;

Figs. 4 and 5 are contiguous viewsy of portions of a modified form of the invention. Fig. 4 shows the upper portion of this embodiment partly in elevation and partly in longitudinal section; and

Fig. 5 illustrating the positions of the parts when the packer is initially set; and

Fig. 6 is a longitudinal sectional view of a portion of the embodiment of Figs. 4 and 5 indicating the position of the various parts during the squeeze cementing operation on the well.

The embodiment of the invention particularly illustrated in Figs. 1, 2, and 3, comprises a pair of packers mounted on an operating pipe or mandrel designated 11, which mandrel is attached to a conduit such as tubing for lowering it into the bore of a well. At its upper end the mandrel has a bore 12 in communication between the tubing and the main bore of the mandrel. At its lower end, the mandrel is closed by a plug 14. The plug 14 has a passage 15 therethrough but fluid cannot at any time ilow from the interior oi the mandrel 11 to a point beneath the plug 14. The passage 15 is connected to an inner by-pass pipe 16 which is in communication with a lateral passage 17 at the :upper end of the mandrel 11.

A cylinder 20 is mounted for sliding movement on the mandrel 11. This cylinder is provided at its upper end with an outwardly extending ilange 21. At its lower end it is threaded into a valve cylinder 22. The flange 21 of the cylinder 20 may be threaded for securing a ring 23 thereon. The ring 23 has an inturned annular flange 24, which cooperates with an outstanding annular flange 25 on the mandrel 11 to act as a stop for limiting relative movement between the mandrel and the cylinder 20.

Within the ring 23 the cylinder 2t) is provided with a vertically extending spline or guide 26. This spline terminates short of the ange 25 on the cylinder 2t) when the parts are in the position shown in Fig. l. The outstanding flange 2S of the mandrel is provided with a notch to receive the spline 26, so that when the mandrel 11 is in its lowered position, as shown in Fig. 3, it is prevented from rotating with relation to the cylinder 20. In its uppermost position, as shown in Figs. 1 and 2, the ilange 25 clears the spline 26, and the mandrel 11 can then be rotated in the cylinder 20.

The valve cylinder 22, to which the cylinder 20 is attached, is threaded into another valve cylinder 32, which in turn is connected to a depending cylinder 33 carrying at its lower end a foot piece 34. It will be seen that the cylinder 20, valve cylinders 22 and 32 and the cylinder 33 constitute a continuous sleeve through which the mandrel 11 can move as a valve body. The parts thus constitute a sleeve valve which can be operated from the surface of the ground by manipulation of the tubing or conduit to which the mandrel 11 is attached..

Cylindrical packer shoes 35 and 36 are positioned over the valve cylinders 22 and 32, respectively. As shown the shoe 35 slidably engages the cylinder 20 while the shoe 36 slidably engages the cylinder 33.

An annular chamber 42 is provided in valve cylinders 22 and 32, which at times is in communication with the ports 43 in the mandrel 11 communicating with the main bore thereof. Passages 44 and 45 lead from the chamo ber 42 to the interiors 46 and 47 of the respective shoes and 36 in order to conduct fluid from the main bore of the mandrel 11 into the shoes when the ports 43 are in alignment with the chamber 42.

Each of the packers is ot' the compression type and preferably. comprises annular elements 50, which are of generally wedge shape in cross-section, and alternate annular resilient members 52. As will be seen from an inspection of Figs. l and 2, when the resilient members 52 are compressed between the elements :'50, upon movement of the shoes 35 and 36 toward the `flange 21 and shoulder 48, respectively, the members 52 Will expand outwardly and be pressed into close engagement with the casing 40. When the shoes 35 and 36 are moved away from the flange 21 and shoulder 43, respectively, the resilient members 52 will contract away from the casing 4G thus returning the apparatus to released position.

The piston member 22 has an internal annular groove 54 therein, which opens through a pasasge 55 into the casing and the mandrel 11 has ports 556 therein, which ports, at times, may be brought into registration with the groove 54 to permit the flow of lluid from the main bore 13 of the mandrel 11 through the piston member 22 into the casing 40 or vice versa. Packing rings such as O- rings, may be provided between the various parts as illustrated.

ln making use of the apparatus of Figs. l, 2, and 3, described above, the mandrel 11 is attached to an oper ating pipe, not shown, with the passage 12 of the mandrel in communication with the pipe. positions shown in Fig. l, the apparatus is lowered into the well to the desired location. As shown in Fig. l, the ilange 25 of the mandrel 11 is at its uppermost position, the packer members are in retracted positions, and the ports 56 are out of registration with the chamber 54 of the valve cylinder 22.

When the apparatus is in the desired position in the casing or bore of the well, fluid under pressure is admitted through the operating pipe and passage 12 of the mandrel 11 into the main bore thereof. The fluid passes through the port i3 into the chamber 42 and through the passages 44 and 45, respectively, into the chambers 46 and 47 of the shoes 3S and 36, moving them longitudinally of the mandrel 11 and the nipple 33, respectively, and compressing the packer between the shoes and the flange 21 and shoulder 48, respectively, to expand the packer elements 52 into engagement with the casing 40 as shown in Fig. 2.

As soon as the packers are thus set in the casing or bore, the mandrel 11 may be rotated until the notch in the ange 25 registers with the spline 26. The mandrel may then be moved downwardly to bring the ports 43 out of registration with the chamber 42, thus locking the pressure in the shoes 35 and 36 so that the packers remain in set position. The mandrel 11 with its ports 43, in cooperation with the chamber 42 thus constitutes a sleeve valve which first supplies lluid under pressure to the packer shoes 35 and 36 and then seals in that iluid under pressure to hold the packers in set position. Further movement of the mandrel 11, to the position in which the flange 25 engages the top of the cylinder Ztl, as shown in Fig. 3, then results in bringing the ports 56 in registration with the groove 54, and fluid under pressure may then pass from the main bore 13 of the mandrel 11 through the groove 54 and out of the passage S5 into the casing or bore of the well. With the apparatus positioned as just described, it is possible to treat the formations adjacent the apparatus by forcing fluid into the same through perforations 68 in the casing 4i), or if desired, lluid from the earth formations may be withdrawn through the perfo rations 68 and flow out through the apparatus for testing or production. lt will be noted that the casing or bore of the well below the apparatus is in communication with the portion of the casing or well bore above the apparatus by way of passage 17 in the mandrel, the internal pipe With the parts in the .fin

16, passage 15 in the plug 14, nipple 33, and the foot piece 34. Thus production or testing of the well may proceed at the same time that the formation horizontally adjacent the apparatus is being tested or treated as by the injection of acid or cement slurry under pressure` To release the apparatus, the mandrel 11 is raised, bringing the port 56 out of registration with the groove 54 and the passage 55. This closes off the main bore of the mandrel 11 from the casing, and brings the ports 53 into registration with the chamber 42 to relieve the pressure in the shoes 35 and 36. This permits the packer elements 52 to contract and release the apparatus. The apparatus may then be withdrawn from the well, or moved to a new location therein for further testing or treatment of the earth formations.

The modification of the invention shown in Figs. 4, 5, and 6, makes use of only a single packer, instead of two as in the previously described form. The apparatus, as illustrated in Figs. 4, 5, and 6, is attached to tubing 69. An operating pipe or mandrel 77 is connected to the lower end of the tubing 69 and it extends down through the safety joint and through a major portion of the packer assembly, as shown in Figs. 4 and 5. The packer assembly and the safety joint are associated with a sleeve 93 on the mandrel 77.

The suspending means for the safety joint and packer assembly consists of a set of pins 7th on the mandrel 77 which supports a hanger for limited longitudinal movement with respect thereto, the pins 7) extending into slots 71 of the hanger 75.

The back-off safety joint includes a housing 73 around the lower portion of the hanger 75. The hanger 75 is provided with a flange 76 at its lower end. An enlargement 73 on the sleeve 93 is connected by safety or backoff threads 80 to the housing '73. The arrangement is such that if the enlargement 7S is disconnected from the housing 73 at the back-oftC threads Sil, the tubing may be withdrawn from the well leaving the sleeve @3 with the slips and packer thereon in the well.

The upper end of the enlargement 7S is clutched as indicated at 83, with the hanger 75. Within the housing '73, a spring 85 is positioned between the flange 76 of the hanger and the top of the housing 73. Thus there can be no relative rotation between the enlargement 78 and the hanger 75 until the enlargement 755 is held stationary in the well bore While the tubing is raised to compress the spring 85. The jaws of the clutch S3 then separate and the housing 73 may be backed off. The housing 73 has a slot 87 therein and the hanger 75 has a pin 23 which ts in this slot so that the housing 73 may be rotated when desired by rotation of the tubing 69 and mandrel 77.

As shown in Figs. 5 and 6, the sleeve 93 has spaced apart llanges 94 and 95, and is threaded at its lower end for the attachment thereto of a piston member 96. The piston member 96 is in turn connected to the foot piece 97 which has an annular flange 98 mediate its ends.

An annular flange 99 is also formed on the lower end of the piston 96, and radially spaced drag shoes 100 are positioned between the flanges 98 and 99. The shoes 160 are urged outwardly by coil springs 101 into engagement with the casing 116 in order to maintain the apparatus in centered position in the well. A ring member 102, having an inturned flange thereon, is positioned over the ange 9d of the sleeve 93 and another ring 103, having an inturned annular flange, is positioned over the ange 95 of the sleeve 93, these rings extending beyond the respective flanges and serving to retain slips 104 in position between the flanges 94 and 95. Expansible pads 105 are mounted beneath the slips 1M to force the same outwardly when fluid pressure is exerted in chamber 107 through ports 16S in the sleeve 93. The bore 112 of the sleeve 93 is larger than the outside diameter of the mandrel 77, as shown, so that fluid can flow along the l sleeve.

A packer shoe 109 is positioned over the piston member 96 providing a chamber 110 which communicates by ports 111 with the bore 112 of the sleeve 93. Between the shoe 109 and the ring 103 on the flange 95 the compression type packer is positioned. This packer is mad: up of spaced ring elements 114 alternately positioned with resilient packing elements 115, adapted, when compressed, to be forced into engagement with the well casing 116 to form a uid tight seal therewith.

The mandrel 77 extends completely through the sleeve 93, the piston member 96, and into the foot piece 97, there being a suitable packing 119 located in the foot piece to form fluid tight engagement with the operating pipe. The mandrel 77 has a restriction near its lower end forming a seat 120 for a ball valve 121, which closes the pipe to downward flow of uid therefrom. Ports 122 are provided in the mandrel 77 just above the ball valve 121, and other ports 123 are spaced above the ports 122 to transmit fluid to the interior of the sleeve 93 when desired. Thus the mandrel 77 with its ports 123, in cooperation with the ports 111 in the sleeve 93 constitute a sleeve valve which can supply fluid under pressure to the shoe 109 to set the packer and then can seal-in that fluid under pressure to hold the packer set. In the same way this sleeve valve controls the slips 104. The slips can be set and then the fluid pressure sealed in to hold them set while squeeze operations are performed with the mandrel 77 moved to any desired position.

The modified form of the invention just described is used as follows:

The packer apparatus is lowered into the well with the clutch in the position shown in Fig. 4 and with the packer members 11S in contracted positions out of contact with the casing. As soon as the apparatus reaches the desired depth in the well, the ball valve 121 in the mandrel 77 comes to rest on valve seal 120. Pressure fluid is then exerted in the mandrel 77, whereupon pressure is applied, through the ports 123 to the bore 112 of the sleeve 93 and thence through ports 108 into the chamber 107 to move the pads 105 and force the toothed slips 104 into biting engagement with the casing 116 to retain the packer apparatus in position.

Pressure fluid also flows from the bore 112 of the sleeve 93 through ports 123 and 111 into the chamber 110 of packer shoe 109. This moves the shoe upward'j from the piston member 96, compressing the packing members 115 between the rings 103 on flange 95 and the shoe 109, and expands them into sealing engagement with the casing. With pressure being maintained within the mandrel 77, the tubing 69 may then be lowered. Dre to the provision of a slip joint, the mandrel 77 may be lowered while the packer assembly remains stationary, the parts then taking the position shown in Fig. 6.

Downward movement of the mandrel 77 with respect to the packer assembly lowers the ports 123 to a point beneath packing 119 to cut olf the llow of pressure fluid into the bore 112 of the sleeve 93. The pressure in the chambers 107 and 110 is maintained however, so that the slips and packer remain in set position. Downward movement of the mandrel 77 also brings the ports 123A into the foot piece 97 so that Huid communication is established between the mandrel 77 and the portion of the well beneath the packer.

When it is desired to release the apparatus, the mandrel 77 is drawn upwardly to close off the ports 122 an;l bring the ports 123 again into the bore 112 whereupon the pressure fluid in the chambers 107 and 110 can escape into the mandrel and release the slips 104 and resilient members 11S from engagement with the casing.

It is to be noted that in the condition of the apparatus shown in Fig. 6, if the apparatus is set in the well for a certain pressure and the pressure below the apparatus becomes higher, then there will be a tendency for the shoe 109 to move downwardly until the pressure inside the chamber 110 balances that in the casing below. Such increased pressure is transmitted to the slip members 104 through the ports 111, bore 112 and ports 108 to force the slip members more firmly into engagement against the casing as the pressure increases.

On the other hand, should the pressure above the apparatus become higher than the effective pressure setting the apparatus, then the resilient members 115 and the shoe 109 will move downwardly, increasing the pressure behind the slip members 104 in the same manner as outlined above, thus setting the apparatus more firmly in position.

The invention provides apparatus by which it is possible to treat or test a well, and affords means by which the earth formations throughout the well may be tested or treated without interfering with production from other formations.

While the arrangements illustrated are described as mounted in casing in a well bore, it will be apparent that by making suitable changes, they may be used in open hole as well. Various changes may be made without departing from the spirit of the invention or the scope of the annexed claim.

I claim:

Apparatus for sealing the lower end of a conduit in a well bore comprising, in combination, a mandrel having a plurality of vertically spaced ports therein, a sleeve mounted on said mandrel for longitudinal movement with respect thereto and having a. plurality of vertically spaced ports which may be brought into alignment with certain ports of the mandrel, means for connecting the mandrel to the conduit, a plurality of sleeve valves including said mandrel and said sleeve operable from the surface of the ground by manipulation of the conduit to selectively control the alignment of ports in said mandrel with ports in said sleeve, two spaced compression type packers mounted on the sleeve, each being adapted to be expanded into fluid-tight engagement with the wall of the well bore, two shoes, one for each packer, slidably mounted on the sleeve for expanding the packers hydraulically, said shoes having a chamber associated therewith adapted upon alignment of certain ports in said mandrel with certain ports in said sleeve to be supplied with fluid under pressure, and means .including one of said sleeve valves for supplying fluid under pressure to said chamber to move said shoes and expand said packers and operable by subsequent manipulation of said mandrel to seal in said chamber the fluid under pressure and hold said packers expanded whereby variable pressure operations may be performed in the well bore between the two packers through another of said sleeve valves without altering the expanded position of said packers.

References Cited in the file of this patent UNITED STATES PATENTS 2,227,731 Lynes Jan. 7, 1941 2,229,635 Boynton Jan. 28, 1941 2,368,399 Baker Jan. 30, 1945 2,370,832 Baker Mar. 6, 1945

Patent Citations
Cited PatentFiling datePublication dateApplicantTitle
US2227731 *Mar 15, 1940Jan 7, 1941John LynesWell formation testing and treating tool
US2229635 *Oct 4, 1938Jan 28, 1941Alexander BoyntonWell testing tool
US2368399 *Jun 23, 1941Jan 30, 1945Baker Oil Tools IncWell packer
US2370832 *Aug 19, 1941Mar 6, 1945Baker Oil Tools IncRemovable well packer
Referenced by
Citing PatentFiling datePublication dateApplicantTitle
US2828823 *Jul 7, 1955Apr 1, 1958Exxon Research Engineering CoReinforced inflatable packer
US2841007 *Jan 10, 1955Jul 1, 1958Loomis Hydraulic Testing Co InApparatus for testing oil well casing or the like
US2860489 *Sep 18, 1953Nov 18, 1958Townsend Lawrence EGrouting or sealing apparatus
US2870846 *Sep 25, 1956Jan 27, 1959Fennon F MooreFormation test tool packer setting tool
US2874782 *Oct 17, 1955Feb 24, 1959Johnston Testers IncDoughnut-type packer
US2935133 *Oct 16, 1956May 3, 1960Jersey Prod Res CoFormation testing
US2942669 *Nov 29, 1957Jun 28, 1960Jersey Prod Res CoInflating pump for oil well packers
US2953919 *Oct 22, 1956Sep 27, 1960Cicero C BrownPipe testing apparatus
US2998721 *Dec 27, 1956Sep 5, 1961Gawlik Paul ATool for detecting pipe leaks
US3034339 *Oct 17, 1957May 15, 1962Paul P FluscheTool for detecting pipe leaks
US3038542 *Aug 11, 1958Jun 12, 1962Loomis Glenn LTester apparatus for oil wells or the like
US3062291 *May 11, 1959Nov 6, 1962Brown Oil ToolsPermanent-type well packer
US3068942 *Dec 7, 1959Dec 18, 1962Brown Cicero CWell packers
US3086387 *Jun 15, 1959Apr 23, 1963Layton Gerald ERetrievable casing tester
US3105378 *May 26, 1958Oct 1, 1963Macro Dev LtdApparatus for testing casing
US3171492 *Oct 9, 1961Mar 2, 1965Cicero C BrownHydraulically set, releasable well packer
US3196959 *Aug 14, 1961Jul 27, 1965Kammerer Jr Archer WDirectional drilling apparatus
US3357504 *Jun 7, 1965Dec 12, 1967Calhoun Gerald GStraddle packer wire line tester
US3439527 *May 12, 1967Apr 22, 1969Rohrer Carl HApparatus for testing gas mains
US3495443 *Apr 2, 1968Feb 17, 1970Phillips Clayton LTubing testing apparatus
US3659648 *Dec 10, 1970May 2, 1972Cobbs James HMulti-element packer
US3693408 *Nov 20, 1970Sep 26, 1972Halliburton CoPipeline testing plug
US3712115 *Oct 9, 1970Jan 23, 1973Lofaso GPipe testing apparatus
US4279306 *Aug 10, 1979Jul 21, 1981Top Tool Company, Inc.Well washing tool and method
US4441561 *Nov 17, 1981Apr 10, 1984Garmong Victor HMethod and apparatus for treating well formations
US4567944 *Feb 9, 1984Feb 4, 1986Halliburton CompanyRetrievable straddle packer
US4569396 *Oct 12, 1984Feb 11, 1986Halliburton CompanySelective injection packer
US4580632 *Nov 18, 1983Apr 8, 1986N. J. McAllister Petroleum Industries Inc.Well tool for testing or treating a well
US4590995 *Mar 26, 1985May 27, 1986Halliburton CompanyRetrievable straddle packer
US4646829 *Apr 10, 1985Mar 3, 1987Halliburton CompanyHydraulically set and released bridge plug
US4856583 *Nov 20, 1987Aug 15, 1989Dresser Industries, Inc.Apparatus for treating well bores
US5152340 *Jan 30, 1991Oct 6, 1992Halliburton CompanyHydraulic set packer and testing apparatus
US7516791May 24, 2007Apr 14, 2009Owen Oil Tools, LpConfigurable wellbore zone isolation system and related systems
US7571765Mar 28, 2008Aug 11, 2009Halliburton Energy Serv IncHydraulic open hole packer
US7832472Jun 30, 2009Nov 16, 2010Halliburton Energy Services, Inc.Hydraulic open hole packer
US7861774May 22, 2009Jan 4, 2011Packers Plus Energy Services Inc.Method and apparatus for wellbore fluid treatment
US8025297 *Nov 6, 2007Sep 27, 2011The Penn State Research FoundationBellows with alternating layers of high and low compliance material for dynamic applications
US8397820Dec 13, 2010Mar 19, 2013Packers Plus Energy Services Inc.Method and apparatus for wellbore fluid treatment
US8590615Oct 15, 2008Nov 26, 2013Hole In One Producer AsCasing device
US8746343Sep 12, 2012Jun 10, 2014Packers Plus Energy Services Inc.Method and apparatus for wellbore fluid treatment
US8973657May 30, 2013Mar 10, 2015Halliburton Energy Services, Inc.Gas generator for pressurizing downhole samples
US20140262290 *Mar 14, 2013Sep 18, 2014Baker Hughes IncorpoaratedMethod and system for treating a borehole
USRE31842 *Sep 3, 1982Mar 5, 1985Top Tool Company, Inc.Well washing tool and method
CN101605963BMay 24, 2007Nov 20, 2013欧文石油工具有限合伙公司Configurable wellbore zone isolation system and related methods
EP0232576A1 *Feb 11, 1986Aug 19, 1987Daniel P. ReardonWell tool for testing or treating a well
WO2007140266A2 *May 24, 2007Dec 6, 2007Owen Oil Tools LpConfigurable wellbore zone isolation system and related methods
WO2009051490A1 *Oct 15, 2008Apr 23, 2009Internat Res Inst Of StavangerCasing device
WO2013106228A2 *Jan 3, 2013Jul 18, 2013Halliburton Energy Services, Inc.Multiple ramp compression packer
WO2013106228A3 *Jan 3, 2013May 30, 2014Halliburton Energy Services, Inc.Multiple ramp compression packer
U.S. Classification166/147, 73/40.50R, 277/342, 166/187, 166/191
International ClassificationE21B33/12, E21B33/124
Cooperative ClassificationE21B33/124
European ClassificationE21B33/124