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Publication numberUS3638732 A
Publication typeGrant
Publication dateFeb 1, 1972
Filing dateJan 12, 1970
Priority dateJan 12, 1970
Also published asCA919581A, CA919581A1
Publication numberUS 3638732 A, US 3638732A, US-A-3638732, US3638732 A, US3638732A
InventorsHanes James W E, Huntsinger Fritz R
Original AssigneeVetco Offshore Ind Inc
Export CitationBiBTeX, EndNote, RefMan
External Links: USPTO, USPTO Assignment, Espacenet
Underwater wellhead electric connection apparatus for submerged electric motor driven well pumps and method of installation
US 3638732 A
Abstract
An underwater bottom hole electrically driven well pump has an electric power cable extending to the wellhead, a connectable and disconnectable electrical connection being provided at the wellhead between the cable and the power cable adapted to extend to a power source, the connection being disconnectable and connectable at the wellhead to permit the pump to be pulled from the well, or run back into the well, through the wellhead and production tree without necessitating removal of the wellhead and production tree.
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Description  (OCR text may contain errors)

O Unite Eiates Fafiei [1 1 3,63%,732 Huntsinger et al, 51 Feb, 1, R972 [54] UNDERWATER WELLHEAD ELECTRIC 2,963,090 12/1960 Cole et al ..l66/85 X CONNEQTKQN APPARATUS FOR 3,045,099 7/1962 Bowman et al. ..l66/60 X 3,339,632 9/1967 Lewis ..l66/.6 SUBMERGED ELECTRHC MQTQR 3,387,657 6/1968 Hardy.... 166/60 DRIVEN WELL PUMPS AND METHOD 3,516,492 6/1970 Petersen ..l66/.6 OF INSTALLATION Primary Examiner-Stephen J. Novosad {72] inventors: Fritz R. Huntsingcr; Jes W. E. es, Attorney-Bernard Kriegel both of Ventura, Calif.

{73] Aseignee: Waco Calif,

1221 Filed: 5m 12,1910

An underwater bottom hole electrically driven well pump has 3 App! 2241 an electric power cable extending to the wellhead, a connectable and disconncctable electrical connection being provided 52 us. ca ..l66/315 166/.6 166/65 wellhead between able and Power cable v 166/85 adapted to extend to a power source, the connection being disconnectable and connectable at the wellhead to permit the 33/035 2 g 9 pump to be pulled from the well, or run back into the well, [5 1 l o n through the wellhead and production tree without necessitat- 166/75 ing removal of the wellhead and production tree.

[56] Referenceg Cited i NE W V 29 Claims, l0 Drawing Figures UNITED STATES PATENTS 5f .cf

PATENTEI} FEB H972 3.638.732

sum 1 or 6 Fin/v5:

PATENTED FEB H972 sum 2 or 6 477 oe/V5 1.

PATENTEU FEB 1 i972 SHEET 5 OF 6 UNDERWATER WELLI-IEAD ELECTRIC CONNECTION APPARATUS FOR SUBMERGED ELECTRIC MOTOR DRIVEN WELL PUMPS AND METHOD OF INSTALLATION The present invention relates to well production apparatus and methods for installing and removing the same, and more particularly to bottom hole electrically driven pumps used in underwater well completions.

Submerged electrically driven pumps have been used on land wells for many years. The electric cable extending downwardly in the well bore to the electric motor passes through the wellhead by means of a pressuretight fitting, running to a suitable electric power source. When retrieval of the pump from such well is necessary, the power line is disconnected from the power source, the wellhead is removed, and the pump and power cable removed from the well. The foregoing arrangement has been used with casing pumps installed in the well bore, in which the pump is run on a wire line, or a string of sucker rods, into the well casing and landed on a casing seat at the desired location of the pump, where it is packed ofi, the well production being pumped up through the casing. In another arrangement, a tubing string is run into the cased well and the pump is run on a wire line or string of sucker rods into the tubing string and landed on a seat therein, at which point the pump is packed off and the production pumped upwardly through the tubing string to the top of the well bore.

It is comparatively difficult and costly to remove and reinstall a wellhead or production tree at the top of a well bore which is to be pumped with an electrically powered submerged pump, particularly where the wellhead and production tree are installed at the mudline or floor of a subsea or other underwater location. As an example, withdrawal of the pump becomes necessary if it sands up, or if the production tree is to be removed for any reason.

By virtue of the present invention, a casing or tubing submersible pump can be removed without the necessity for removing the wellhead or production tree, and the electric motor-operated pump can also be run to its landing position in the casing or tubing without materially disturbing the wellhead or production tree. Accordingly, the remedial cost of pump replacement is reduced to a minimum.

The invention further involves the provision of an electrical connection at the wellhead or production tree between the electric cable extending downwardly from the production tree or wellhead to the electric motor driven pump and a power cable extending from the wellhead or production tree to a suitable remotely located power switch, the electric connection being readily connectable and disconnectable without removal of the production tree or wellhead, to permit the pump and cable connected thereto to be removed through the wellhead. If tubing is in the well casing and it sands up, the tubing can also be removed without removal or other disturbance of the production tree or wellhead.

In connection with an underwater well bore and wellhead, the electrical connection at or adjacent to the wellhead can be readily disconnected or connected to permit withdrawal of the pump or tubing string, if one is present, from the well bore, and the rerunning of such equipment in the well bore, all without affecting the wellhead or production tree.

This invention possesses many other advantages and has other purposes which may be made more clearly apparent from a consideration of several forms and methods embodying the invention. These forms and methods are shown and described in the present specification and in the drawings accompanying and constituting a part thereof. They will now be described in detail, for the purpose of illustrating the general principles of the invention; but it is to be understood that such detailed description is not to be taken in a limiting sense.

Referring to the drawings;

FIGS. la and lb together constitute a combined longitudinal section and side elevational view of one embodiment of the invention, FIG. 1b being a lower continuation of FIG. la;

FIG. 2 is an enlarged longitudinal section through the electrical connector portion of the apparatus illustrated in FIG. la, with the electrical connection completed;

FIG. 3 is a view similar to FIG. 2, disclosing parts of the electrical connector in disengaged position;

FIG. 4 is a longitudinal section, on an enlarged scale, of a releasable connection between the cable and pump forming part of the apparatus illustrated in FIG. 1b;

FIGS. 50 and 5b together constitute a combined longitudinal section and side elevational view of another embodiment of the apparatus, FIG. 5b being a lower continuation of FIG. 5a;

FIG. 6 is a combined longitudinal section and side elevational view of yet another fonn of the invention;

FIG. 7 is an enlarged combined longitudinal section and side elevational view through the electrical connector portion of the apparatus illustrated in FIG. 6;

FIG. 8 is a cross section taken along the line 88 on FIG. 7.

The form of invention illustrated in FIGS. 1 to 4 involves a casing type of electric motor-driven pump 10 of any known, usual design, which is disposed in a casing string 11 located in a well bore A and passing through a plurality of producing zones I2, the production passing into the lower portion of the casing string through a plurality of perforations l3, and then through inlet perforations 14 into the submerged pump 10, which is landed on a casing pump seat 15 in sealed relation thereto. The well bore A underlies a body of waterand extends downwardly from the mudline of floor M underlying the water. A typical wellhead combination W is disclosed in connection with the casing string. Thus, the bowl 16 of a guide structure rests upon the floor M, having ports 17 at its lower end. A hanger 18 for a string of conductor casing 19 is supported on a shoulder 20 of the guide structure, the conductor pipe extending downwardly from the mudline M to a desired depth. Another casing hanger 21 seats upon a shoulder 22 in the conductor hanger 18, a protection casing string 23 being secured thereto, and depending downwardly in the well bore to a required depth, which is usually substantially below the depth to which the conductor casing 19 extends. The produc tion casing string 11, in which the pump 10 is disposed, is secured to a casing hanger 24 resting upon a shoulder 25 in the hanger housing 21 secured to the protection casing string 23.

The manner of running the various strings of casing and the completion of the casing system is known. In general, the entire guide structure is supported on the drilling vessel (not shown), together with the bowl 16, which is an integral part of the guide structure. The conductor hanger 18 is held in the guide structure 16 by means of a lock ring 26, and the desired length of conductor 19 is secured to the conductor hanger. This combination is now lowered by means of a left-hand running tool (not shown) on drill pipe (not shown), the running tool threadedly engaging the left-hand threads 27 of the conductor hanger, and also being provided with a stinger (not shown) with a jetting head (not shown) at its lower end that is disposed inside the conductor pipe 19 and terminates a short distance from the bottom of the latter. A suitable fluid is pumped down the stinger for discharge from the jetting head, when the whole combination has been lowered to the point in which the lower end of the conductor is at the mudline M, to jet the desired length of hole in the formation, which will be determined by the engagement or landing of the guide structure 16 on the mudline. The annulus surrounding the conductor pipe 19 is now cemented in place in a known manner, with the cement returns coming up the annulus and spilling over at the mudline through the ports 17 in the bowl. The running string is now retrieved by unscrewing the running tool at the left-hand threads 27 of the conductor hanger.

If jetting of the hoe is not feasible, then a drill bit and hole opener combination (not shown) is run through the conductor 19 and a hole made for the latter. While the drill string with the drill bit and expanding hole opener are still in communication with the hole, the conductor pipe 19 and the guide base and its bowl 16 are stripped into the hole by lowering it on guide lines (shown in FIG. 6). The drilling string is then removed and the conductor 19 cemented in place by a known displacement method.

The drilling of the well bore A is continued by means of suitable drilling bits and a drilling string to a desired depth to receive the protection string of casing 23. This protection string is secured to the hanger housing 21 by means of a suitable left-hand threaded running tool which threadedly engages the left-hand threads 28 of the hanger housing 21. This combination is lowered from the drilling vessel until the hanger housing 21 lands in the conductor hanger, resting upon the shoulder 25 of the latter, the hanger housing carrying a split expandable lock ring 29 therein which contracts past the lock ring 26, secured to the bowl 16, and then snaps into an internal groove 36 formed between the lock ring 26 and the hanger housing 18 to prevent upward movement of the inner hanger housing 21. The protective casing string 23 is then cemented in place, with the returns passing through a passage 31 in the hanger housing and dumping into the ocean near its floor. The running tool is then retrieved by unscrewing it at the left-hand thread 28 of the hanger housing 21.

A blowout preventer stack (not shown) is secured to the lower portion of a marine riser (not shown) and is run in place from the drilling vessel and connected to the wellhead by means of a connector similar to a connector 32 shown in the drawings, the connector resting upon the top of the hanger housing 21 and carrying an inherently contractable lock ring 33 in its groove 34 which will snap into a peripheral groove 35 in the upper portion of the hanger housing.

A. hole A is now drilled to the desired depth and through the producing zones 12, and of a diameter to receive the production casing string 11 in which the pump is to be installed. By means of a suitable running tool connected to the casing hanger 24 secured to the production casing string 11, the latter is lowered from the drilling vessel through the marine riser and blowout preventing stack into the well bore A to the extent at which the casing hanger 24 lands on a shoulder 37 in the hanger housing. The casing string 11 is now cemented in place, beginning at the top of the producing zones 12, the cement 40 discharging through a suitable cement collar 38 and then passing upwardly through the annulus 39 surrounding the production casing string to a location above the rnudline, the cement dumping out through the opening 41 provided by the removal of a plug 42 for the opening by a diver prior to the commencement of the casing cementing operation.

The blowout preventer stack, marine riser, and connector are now removed, and a production tree 43, with a connector 32 attached to its lower end, then lowered from the drilling vessel and attached to the wellhead hanger housing 21. A tubular extension M is threadedly secured to the lower end of the production tree, its lower end terminating just above the upper end of the production casing string 11 so as to provide continuity of the passage for the pump 10 through the apparatus when it is being elevated from the casing, and when it is lowered thereinto to its position at which it lands on the pump seat in the lower portion of the production casing string. The production tree 43 has a lateral flow line 45 communicating with the central passage through the tree, which is secured to the tree in any suitable manner, as by means of a clamp connection 46. The flow line has a suitable valve 47 therein for shutting off or permitting flow of fluid therethrough.

The upper portion of the production tree 43 is provided with a shutoff valve 48 and a quick connection 49, which allows for connecting a small production riser 50 between the production tree and a workover vessel (not shown) floating in the top of the water.

As disclosed in the drawings, the pump 10 is connected, preferably by means of a releasable connection 51, to a cable 32 which combines a steel supporting cable with electrical conductors therein, the upper ends of which are secured to a landing head 53 adapted to land on an upwardly facing inter- LII nal shoulder 54 in the production tree or head (FlGS. 2,3). The upper steel cable portion is sec$red to a depending skirt or leg portions 55 of the pump landing head by means of screws 56 secured to a socket 57 into which the upper portion of the cable extends and is s$itably secured, the conductor portion or portions 58 of the cable itself extending upwardly into an axial passage 59 in the landing head, each of the conductors being received within one portion of a conductive sleeve 60 that has a branch 61 forming a female socket 62 of an electrical connector C, extending radially toward a radial passage 63 in the pump landing head and terminating inwardly of the passage 63 and periphery of such head 53. Dielectric material 64, such as nylon, is cast in the head passage 59, being secured to the head by integral circumferential ribs 65 of the dielectric insulating material being received within internal grooves 66 in the head. For the purpose of running-in and retrieving the pump, a connector 67 is threadedly secured in the landing head above the dielectric material, this connector having a fishing neck 68 and head 69 at its upper portion adapted to coact with a suitable running too] 70 (H6. 50) attached to the lower end of a wire line 71, by means of which the pump 10, cable 52 and landing head 53 are run in and also retrieved.

The production head 43 has a lateral extension 73 which forms part of a connectable and disconnectahle electrical connector mechanism. It is necessary to orient the lateral or radial extension 73 with the pump landing head opening 63 and with respect to the socket 62 disposed therein, the socket and opening 63 being in a position for appropriate alignment with the axis of the lateral arm 73 of the production head when the pump landing head 53 lands upon its companion shoulder 54. The parts are properly oriented, as a result of lowering the pump landing head in the production head, by providing a longitudinal key 74 on the landing head diametrically opposite the lateral landing head passage 63, the lower end of the key engaging an upwardly directed surface of a helical cam 75 extending around the production head 43, so that upon axial sliding of the key along the cam, the pump landing head 53 is turned to an extent at which its landing on its companion shoulder 54 positions the lateral passage 63 and the socket 62 in coaxial relation with the lateral arm 73 of the production head.

Axially slidably mounted within the arm 73 is a connector sleeve 76 which is prevented from rotating with respect to the arm 73 by a radial pin 77 secured to the arm and slidable in a longitudinal groove or keyway 78 in the sleeve 76. This sleeve has a male conductive plug 79 which is affixed to the conductive terminal of a conductor 80 forming part of a power cable 81 extending to a suitable power source above water or on an adjacent shore. The male plug 79 and conductor 80 disposed within the connector sleeve 76 are held therein and insulated therefrom by molding a suitable dielectric material 82 in the sleeve and around the conductive members, the insulating material being secured in place by integral circumferential ribs 83 thereon received in companion internal grooves 84 in the connector sleeve 76. Extending axially from the female socket 62 is a flaring mouth 85 of the insulating material 64 adapted to coact with a companion tapered portion 86 at the inner end of the insulating material 82. The insulating material 64 has ,another tapered or outwardly flaring surface 8'7 adapted to coact with the companion tapered surface 88 on the insulating portion 82, to provide assurance that the engagement of the tapered surfaces with one another will provide a leakproof seal therebetween (see FIG. 2).

The connector sleeve 76 is shifted axially of the arm 73 to bring the male plug 79 into a position fully received within the female socket and making good electrical contact therewith. initially, the sleeve 76 is in its outer position so as not to obstruct the passage 90 in the production head 43, there being one or a plurality of seal rings 91 in the arm slidably and sealingly engaging the periphery of the connector sleeve 76 to prevent passage of fluid therebetween. The landing head 53 carries a suitable seal ring 92 in a position surrounding its radial passage 63 which is adapted to be engaged by the periphery of the connector sleeve 76 when the latter is moved inwardly thereinto, to prevent leakage of fluid therebetween. Initially, the cavity 63 in the landing head 53 with which the socket 62 is aligned is filled with a silicon jell 93 which has high dielectric characteristics. The movement of the connector sleeve 76 and its interior parts toward and into the cavity will cause the fluid in advance thereof to pass through the clearance space between the landing head 53 and the production head 43, until the connector sleeve 76 engages the head seal ring 92, whereupon the silicon jell is forced out of the cavity 63 through a passage 94 in the pump landing head, the silicon jell moving through a suitable check valve 95 into the production head 43 above the landing head. The check valve, which may be of the spring loaded ball type, permits outward flow of fluid substances from the cavity 63 and passage 94 to the exterior of the landing head 53, but prevents return flow of fluid thereinto. Inward feeding of the connector sleeve 76 continues until the tapered surfaces 85, 86 and 87, 88 (FIG. 2) coengage.

After the landing head 53 is disposed in its appropriate position within the production head 43, and with its radial cavity 63 aligned with the lateral arm 73, the connector sleeve 76 is moved inwardly. As specifically illustrated in the drawings, its longitudinal shifting is effected by means of a nut 100 having a threaded connection with the arm 73. This nut has an inwardly directed flange 101 received within a peripheral groove 102 in an outer portion of the connector sleeve, the nut being rotatable by a diver grasping a radial rod 103 suitably affixed to the nut. Rotation of the nut 100 in one direction will feed it outwardly along the arm 73 to the extent limited by engagement of a set screw 104 threaded in the inner portion of the nut with a stop shoulder 105 on the arm. When such engagement occurs, assurance is had that the connector sleeve 76 and the insulation 82 therein, as well as the male plug conductor 79, have been removed completely from the passage 90 extending through the production head 43. In the event that the production tree is to be removed from the hanger housing 21, the set screw 104 can be completely unthreaded from the nut and the latter threaded completely off the tubular arm 73, permitting the connector sleeve 76 and parts therewithin to be removed completely from the arm.

Rotation of the rod 103 and nut 100 in the opposite direction from that just described will feed the connector sleeve 76 inwardly for the purpose of making the electrical connection between the female socket 62 and the male plug 79, as described above.

In running the submersible pump into the well bore, the connector sleeve 76 and each male plug 79 are disposed within the production head arm 73 in their outer position completely clear of the production head passage 90. The electric motor pump 16 is connected to the cable 52, the upper end of which is secured to the pump landing head 53 by means of a support member 57 and the screws 56. The cavity 63 is filled with the silicon jell 93 and the running tool 70 attached to the fishing head 69 secured to the landing head 53, the combination of apparatus then being lowered from the drilling vessel through the production riser 50, production head 43 and into the casing 11, until the submersible pump 10 lands on and seals against the pump seat 15, the key 74 contacting the cam surface 75 in the production tree and orienting the landing head 53 so that its cavity 63 and socket or terminal 62 are appropriately locating with respect to the production head arm 73 when the head 53 lands upon its companion shoulder 54 The rod 103 and nut 106 are then rotated to feed the connector sleeve 76 axially inwardly of the arm, the silicon jell 93 being displaced outwardly through the passage 94 and springloaded check valve 95 until the connector sleeve is disposed to its maximum inward extent, at which time the tapered surfaces 85, 86 and 87, 88 coengage and the socket 653 fits snugly in good electrical contact around the male plug 79.

The running tool 70 is now released from the head 69 and the marine production riser 50 removed, the valve 43 being closed and the valve 47 in the flow line 45 opened. Oil from the several oil producing zones 12 migrates down the annulus B around the production casing string 11, passing through the casing perforations 13 into the casing below the pump 10. The production is sucked up by the pump through the perforated tail pipe and is pumped up through the casing 11, discharging through the flow line 45 to the storage tanks (not shown), or the like.

In the event it is desired to pull the pump 10 from the easing, the flow line valve 47 is closed and the shutoff valve 48 opened. The nut 100 is rotated in a direction to feed the connector sleeve 76 outwardly and break the electrical connection between the male plug 79 and the female socket 62, the sleeve being moved outwardly to its fullest extent so that the sleeve, male plug and dielectric material 82 are completely removed from the production head passage 90 (FIG. 3). Thereafter, a retrieving tool 70 (FIG. 5a) is lowered on a wire line 71 from a floating vessel, the retrieving tool being connected to the fishing head 69, in a known manner. An upward pull is now taken on the wire line and retrieving head to pull the pump landing head 53, cable 52 and pump 10 upwardly, the upward movement continuing until the pump has been completely removed and elevated to the floating vessel. Such action takes place without disturbing the casing heads and casing strings attached thereto. If desired, the production tree 43 can be completely disconnected from the hanger housing 21 by releasing the manual connector 32 therefrom, in a known manner.

In the event that a sand body has built up on top of the pump 10, which prevents its release and removal from the production casing string 11, a breakaway fitting or releasable connection 51 between the lower portion of the cable 52 and the pump 10 is provided so that the cable can be disconnected from the pump, thereby permitting the cable 52 and landing head 53 to be retrieved. Thereafter, a suitable fishing tool can be lowered into the casing for the purpose of jarring the pump loose and effecting its recovery from the casing.

A breakaway or releasable cable connection 51 to the pump is illustrated in FIG. 4. As shown therein, the upper end of the electric motor driven pump 10 has a male plug or terminal 121 fitting within a female socket or terminal 122 embedded in dielectric material 123 cast within a conductor housing 124 having an external flange 125 secured to the end portion of the motor case or housing by a plurality of longitudinally extending cap screws 126 designed to pull apart or fail when subjected to a predetermined tensile pull. The conductor housing 124 is filled with dielectric material 127 through its upper end, which will surround the electric conductor 128 connected to the female terminal 122, the bleeding of air from the housing during the filling operation being permitted by the provision of a vent port 129 in the lower portion of the conductor housing. The housing 124 is threadedly secured to a spelter socket 130 into which the cable 52 extends. The steel strands of the cable are separated and spread apart in the spelter socket, after which the socket is filled through a port 131 with a resin 132 which firmly anchors the steel cable strands to the socket 130, and also the conductor housing 124 connected thereto.

In the event the taking of an upward pull on the wire line 71, retrieving tool 70, pump landing head 53, and cable 52 does not result in the retrieving of the submersible pump 10, the extent of such pull can be increased until, at a predetermined force, the cap screws 126 will pull apart, thereby effecting a breaking of the connection between the conductor and the pump by virtue of the pulling off of each female conductive sleeve 122 from its male plug 121. The equipment in the casing and production head can now be elevated completely therefrom and withdrawn to the floating vessel, after which, as stated above, a suitable fishing tool can be lowered for recovery of the submersible pump.

In the form of invention illustrated in FIGS. 5:: and 5b, the electric motor-driven pump 10 is disposed in a tubing string 200 run into the casing string II. The tubing string extends into the casing string to a location within the production zone region 12 of the casing, a packer 201 on the tubing string sealing off against the inner wali of the well casing below the easing hanger 24, such location being determined by a tubing hanger 202 engaging a supporting shoulder 203 on the production tree housing 43, the tubing hanger being held in place by a lock screw 204 threaded into the Christmas or production tree housing and received within a peripheral groove 205 therein. The tubing string has perforations 206 above the location of the packer 201, so that the oil delivered by the pump into the tubing string 200 can flow outwardly through the perforations and into the lateral branch 45 of the flow line controlled by the valve 47. A seat protector 207 may be disposed in the hanger housing to protect the lateral branch of the flow line, but such seat protector is removed before the tubing string 200 is run in the well bore by means of the Christmas tree housing, the manual connector 32 securing the latter to the hanger housing 21 in the same manner as in the other form of the invention.

The pump landing head 53, lateral electric connector 73, 76, 100, etc., orienting key 74 and cam 75, running-in head 67-69, and the like, are the same as in the other form (FIGS. 1 to 4) of the invention, except that the landing shoulder 54 for the landing head may provided by the upper end of the tubing hanger 202.

The pump is run in on the cable 52 and pump landing head 53 in the same manner as in the other form of the invention, until the pump lands on its tubing seat 15. The electric connection and disconnection at the landing head is made in the same manner as in the other form of the invention. in the event that the tubing becomes sanded up above the pump 10, precluding the latter from operating, the electric connector is disconnected in the same manner as in the other form of the invention, nd the retrieving tool 70 lowered to engage the retrieving head 69 for withdrawal of the pump. In the event that the sand in the casing prevents recovery of the pump, then a pull can be taken on the cable 52 in a sufficient amount to disrupt the breakaway fitting 51 in the same manner as in the other form of the invention, whereupon the cable 52 and the pump landing head 53 can be retrieved. The lock screw 204 is then released and through use of suitable retrieving mechanism coupled to the tubing hanger 202, the tubing 200 with the pump 10 therein can be withdrawn from the well bore.

As in the other form of the invention, the casing hanger heads 18, 21, 24 and the Christmas tree housing 43 need not be disturbed before the pump 10 can be retrieved. The pump or another pump can be relowered in the well bore and placed in operative association with the tubing seat 15, the electric connector C being reconnected so that the pump can commence its pumping action to deliver the well production through the flow line 45 to storage tanks, or the like.

in the embodiment of the invention illustrated in FIGS. 6 to 8, essentially the same assembly of casing hangers 18, 21, 24 and concentric strings of casing 19, 23, 11 are disclosed as in the other forms of the invention. A tubing string 200 is lowered into the production casing string 1 1, the upper end of this string of tubing being threadedly secured to a tubing hanger 302 adapted to come to rest upon a suitable shoulder 303 in the casing hanger 24 and releasably held in position by a split latch ring 304 disposed in a peripheral groove 305 in the tubing hanger receivable in an internal circumferential groove 306 in the casing hanger. The opposed sides of the groove 306 are tapered so that an upward pull taken on the tubing hanger 302 will cam the latch ring 304 inwardly and permit removal of the tubing hanger 302 and tubing 200 from the casing hanger 24 and casing string 11.

The electric conductor cable 52 is also suspended from the tubing hanger 302, the lower end of the electrical conductor making a suitable electrical connection with the pump 10 disposed in the production tubing 200. As shown, the upper end of the cable is secured to a support member 310 having a flange 311 resting upon a shoulder 312 in the tubing hanger 302 and being held downwardly thereagainst by a retainer ring 313 attached to the tubing hanger by longitudinally extending cap screws 314. The outer steel stranded portion of the conductor cable is suitably mounted in the support member 310, and each of its conductors 58 extends upwardly through dielectric material 315 being attached to the cast into the support member 310, the dielectric body 315 being attached to the support member by integral ribs 316 thereon cast into internal grooves 317 in the support member. The dielectric material extends slightly above the upper end of the support member, each conductor 58 therein projects upwardly out of the dielectric material to form a maie plug or terminal 318. The electrical connector C also includes an outer housing 319 adapted to telescope over the support member 310 and to be sealed thereagainst by means of one or more side seal rings 320 carried by the housing and sealingly engaging the periphery of the support member. One or more companion electric conductors are disposed in the outer housing 319, being held therein by dielectric material 321 cast within the housing passage and secured thereto by dielectric ribs 322 received within companion internal grooves 323 in the housing. Each conductor 80 in the housing is secured to a female conductive sleeve 79 adapted to receive the terminal plug 318. The dielectric member 321 projects below the sleeve or sleeves 79, tapered surfaces 324 on the dielectric bodies 315, 321 engaging when the connection has been completed, to seal each connection 79, 318 against passage of fluid.

The housing 319 is carried by the upper end member or portion 325 of the manual connection 32 which is adapted to telescope over the hanger housing 21. Thus, the outer housing 319 has a shoulder 326 engaging the lower side of the end plate 325 of the manual connector, a lock nut 327 being threaded on the reduced diameter portion of the outer housing and bearing against the upper side of such end plate. Leakage of fluid along the housing is prevented by a suitable seal ring 328 on the end plate sealingly engaging the periphery of the housing.

A production nipple 329 is received in the passage 330 of the tubing hanger 302 in which the production tubing 200 is connected, the upper portion of this nipple being sealed within the end plate 325. The oil delivered by the pump 10 through the tubing 200 will pass through the nipple 329 and into a Christmas tree assembly 331 thereabove of any suitable combination of elements.

The female connector member 79, 80, 321 is attached to an electrically conductive cable 340 extending to a fitting 341 carried by a bracket 342 suitably secured to the end piate 325. The power cable (not shown) leading from the power source is suitably attached to the cable 340 in the fitting 341 by means of a suitable electrical connector (not shown) that can be threadedly secured to the fitting, in a known manner.

The tubing hanger 302 is properly oriented with respect to the hanger housing 21 by means of a spring-loaded orienting key 343 mounted in the tubing hanger 302 and adapted to be received in a single orienting longitudinal keyway 344 out across the threaded portion 345 of the housing. By turning of the tubing hanger 302, the key 343 snaps into the orienting keyway 344, which places the production tubing 200 and the male connector 310 in an appropriate relation for reception of the manual connector 32 and the fitting 329 and electrical connector member 319 carried thereby, when the connector 32 is lowered along suitable guidelines extending to the floating vessel and secured to lower guide posts 350.

The production tubing 200, pump 10 and electricai conductor 52 are lowered from the floating vessel, the production tubing and electrical conductor entering the production casing 11 and being appropriately disposed to locate the lower portion of the tubing and the pump carried thereby at the desired location in the well casing, s determined by engagement of the tubing hanger 302 with its seat 303, its lock ring 304 snapping into the companion locking groove 306 in the casing hanger 24. The lowering tool, such as a string of drill pipe (not shown) releasably secured to the tubing hanger 302 is then turned until the key 343 snaps into the keyway 344, which insures the proper orienting of the tubing string 200 and of the male electrical connector members 58 relative to the hanger housing 21, which has been located in a predetermined position by means of its guide arms 360 and sleeves 361 slidable along the posts 350 secured to the guide structure of the assembly illustrated in the drawings. As set forth above, suitable guidelines (not shown are connected to the guide posts 35%, which extend to the drilling vessel.

The Christmas tree assembly 331 with the manual connector 32 is then lowered from the drilling vessel, the manual connector having a guide frame 362 and sleeves 363 also slidable along the guidelines, and then along the guide posts 350, the nipple 329 being appropriately aligned with the passage 330 in the tubing hanger 302, and the outer housing 319 of the electrical connector C being aligned with the male portions 318, 315, 316 of the electrical connector, which are secured to the tubing hanger 302. The connector 32 is lowered to its fullest extent over the hanger housing 21, which will place the nipple 329 in sealed relation within the hanger passage 330 and which will also telescope the outer housing 319 over the lower cable support 310 and lace the conductor sleeves 79 over the male plugs 318. The cavity 365 present within the outer hous ing 319 of the female connector is filled with silicon jell prior to lowering of the connector and Christmas tree toward the ocean floor M. Upon disposition of the outer housing 319 over the lower support 310, such silicon jell is forced out of the cavity through a spring-loaded check valve 366 to the exterior of the outer housing, thus insuring that any sea water, or the like, or other liquid in the outer housing 319 will be dispelled from the outer housing cavity, and thus insuring the presence of a good electrical connection between the male terminal plugs 318 and the female terminal sleeves 79.

in the event that retrieval of the pump is required, the mechanical connector 32 is released from the hanger housing 21 and elevated, together with the Christmas tree 331 thereabove, to the drilling vessel, the bridging nipple 329 being removed from the tubing hanger 302 and the female portions 319, 321, 80, 79 of the electrical connector C being disconnected from the male portions 310, 315, 58 carried by the tubing hanger. Thereafter, a suitable retrieving tool can be lowered on a suitable string of tubing and connected to the tubing hanger 302, an upward pull being taken on the retrieving string to cause retraction of the lock ring 306 from the casing hanger groove 306 and withdrawal of the tubing hanger 362 from the casing hanger 24, as well as elevation of the tubing string 2M), pump it) and electrical conductor 52 as a unit completely from the casing 11 and to the floating vessel.

We claim:

1. ln apparatus for conducting electric current to an electrically operated subsurface device disposed in a well bore: hanger means at the top of the well bore; a landing head removably supported in said hanger means; first electric conductor means in said landing head having a first terminal; a support shiftable into and from operative relation to said landing head; second electric conductor means carried by said support and having a second terminal adapted to be brought into and from contact with said first terminal in response to movement of said support relative to said landing head; coengaging orienting means on said landing head and hanger means placing said first electric conductor means in a position aligned with said second electric conductor means; said shiftable support and second conductor means being movable from obstructing relation to said landing head to permit withdrawal of said landing head from said hanger means.

2. In apparatus as defined in claim 1; said support being mounted in said hanger means and shiftable therein in one direction to contact said second terminal with said first terminal and in the opposite direction to disconnect said second terminal from said first terminal to remove said support and second conductor means from said obstructing relation to said landing head.

3. ln apparatus as defined in claim 1; said support being shiftable into said landing head to contact said second terminal with said first terminal and out of said landing head to disconnect said second terminal from aid first terminal and to remove said support and second conductor means from said obstructing relation to said landing head.

4. In apparatus as defined in claim 1; said landing head being movable longitudinally of said hanger means into and out of said hanger means; said support being shiftable longitudinally into said landing head to contact said second terminal with aid first terminal and longitudinally out of said landing head to disconnect said second terminal from said first terminal and to remove said support and second conductor means from said obstructing relation to said landing head.

5. ln apparatus as defined in claim 1; said support being shiftable longitudinally of aid landing head in one direction to contact said second terminal with said first terminal and in the opposite direction to disconnect said second terminal from said first terminal and to remove said support and second conductor means from said obstructing relation to said landing head.

6. In apparatus as defined in claim 1; and means for preventing fluid from passing to said first and second tenninals when said terminals are in full contact with each other.

7. ln apparatus as defined in claim 1; and means for placing said landing head in a predetermined position within said hanger means to insure alignment between said terminals.

8. In apparatus for conducting electric current to an electrically operated subsurface device disposed in a well bore: hanger means at the top of the well bore; a landing head removably supported in said hanger means; first electric conductor means in said landing head having a first terminal; a support shiftable into and from operative relation to said landing head; second electric conductor means carried by said support and having a second terminal adapted to be brought into and from contact with said first terminal in response to movement of said support relative to said landing head; said shiftable support and second conductor means being movable from obstructing relation to aid landing head to permit withdrawal of said landing head from said hanger means; said hanger means having a longitudinal passage in which said landing head is supported; said support being mounted in said hanger means and shiftable therein in one direction laterally of said passage and into said passage to contact said second terminal with said first terminal and in the opposite direction to disconnect said second terminal from said first terminal and to remove said support and second conductor means completely from said passage.

9. [n apparatus for conducting electric current to an electrically operated subsurface device disposed in a well bore: hanger means at the top of the well bore; a landing head removably supported in said hanger means; first electric conductor means in said landing head having a first terminal; a support shiftable into and from operative relation to said landing head; second electric conductor means carried by said support and having a second terminal adapted to be brought into and from contact with said first terminal in response to movement of said support relative to said landing head; said shiftable support and second conductor means being movable from obstructing relation to said landing head to permit withdrawal of said landing head from said hanger means; and coengaging means on said landing head and hanger means for turning said landing head to a predetermined angular position in said hanger means to insure alignment between said terminals.

11). in apparatus as defined in claim 9; said hanger means having a longitudinal passage in which aid landing head is supported; said support being mounted in said hanger means and shiftable therein in one direction laterally of said passage and into said passage to contact said second terminal with said first terminal and in the opposite direction to disconnect said second terminal from aid first terminal and to remove said support and second conductor means completely from said passage.

11. in apparatus for conducting electric current to an electrically operated subsurface device disposed in a well bore:

hanger means at the top of the well bore; a landing head removably supported in said hanger means; a first cable carried by and depending from said landing head, said cable having one or more first electric conductors, each conductor having a first terminal, dielectric material in said head insulating said one or more conductors from said head; a support shiftable into and from operative relation to said landing head; a second cable extending from said support, said second cable having one or more second electric conductors, each second conductor having a second terminal, dielectric material in said support insulating said one or more second conductors from said support; shifting of said support toward said landing head contacting said one or more second terminals with said one or more first terminals; said support and second electric conductors being movable from obstructing relation to said landing head to permit withdrawal of said landing head from said hanger means.

12. in apparatus as defined in claim 11; and coengaging means on said landing head and hanger means for turning said landing head to a predetermined angular position in said hanger means to insure alignment between said one or more first terminals and said one or more second terminals.

13. In apparatus as defined in claim 11; said hanger means having a longitudinal passage in which said landing head is supported; said landing head having a cavity therein into which said support is movable to contact said one or more second terminals with said one or more first terminals, said support being withdrawable from said cavity to remove said one or more second terminals from contact with said one or more first terminals and from said cavity to permit withdrawal of said landing head from said hanger means.

14. In apparatus as defined in claim 11; said hanger means having a longitudinal passage in which said landing head is supported; said landing head having a cavity therein, said cavity axis extending laterally of the axis of said passage; said support being shiftable on said hanger means laterally of said passage and into and from said passage and cavity to selectively contact said one or more second terminals with said one or more first terrnin als or to remove said one or more second terminals from contact with said one or more first terminals and said support from said passage to permit withdrawal of said landing head from said hanger means.

15. in apparatus as defined in claim 11; said hanger means having a longitudinal passage in which said landing head is supported; said landing head having a cavity therein, said cavity axis extending laterally of the axis of said passage; said support being shiftable and said hanger means laterally of said passage and into and from said passage and cavity to selectively contact said one or more second terminals with said one or more first terminals or to remove said one or more second terminals from contact with said one or more first terminals and said support from said passage to permit withdrawal of said landing head from said hanger means; and means for shifting said support on said hanger means into and from said passage and cavity.

16. in apparatus as defined in claim 11; said hanger means having a longitudinal passage in which said landing head is supported; said landing head having a cavity therein, said cavity axis extending laterally of the axis of said passage; said support being shiftablc on said hanger means laterally of said passage and into and from said passage and cavity to selectively contact said one or more second. terminals with said one or more first terminals or to remove said one or more second terminals from contact with said one or more first terminals and said support from said passage to permit withdrawal of said landing head from said hanger means; and means for shifting said support on said hanger means into and from said passage and cavity; said shifting means comprising a nut coupled to said support and threaded on said hanger means, whereby rotation of said nut feeds said support laterally of said passage.

17. In apparatus adapted for use in a well bore having a tubular string therein: an electrically operated subsurface device adapted to be set in the tubular string; hanger means at the top of the well bore; a landing head removably supported in said hanger means; a first electric conductor means extending from said device to said landing head and having a first terminal in said landing head; a support shiftable into and from operative relation to said landing head; second electric conductor means carried by said support and having a second terminal adapted to be brought into and from contact with said first terminal in response to movement of said support relative to said landing head; said shiftable support and second conductor means being movable from obstructing relation to said landing head to permit withdrawal of said landing head, first conductor means and subsurface device from the well bore and hanger means.

18. in apparatus as defined in claim 17; said support being mounted in said hanger means and shiftable therein in one direction to contact said second terminal with said first terminal and in the opposite direction to disconnect said second terminal from said first terminal and to remove said support and second conductor means from said obstructing relation to said landing head.

19. In apparatus as defined in claim 17; said hanger means having a longitudinal passage in which said landing head is supported; said support being mounted in said hanger means and shiftable therein in one direction laterally of said passage and into said passage to contact said second terminal with said first terminal and in the opposite direction to disconnect said second terminal from said first terminal and to remove said support and second conductor means completely from said passage.

20. in apparatus as defined in claim 17; said landing head being movable longitudinally of said hanger means into and out of said hanger means; said support being shiftable longitudinally into said landing head to contact said second terminal with said first terminal and longitudinally out of said landing head to disconnect said second terminal from said first terminal and to remove said support and second conductor means from said obstructing relation to said landing head.

21. in apparatus as defined in claim 17; said hanger means having a longitudinal passage in which said landing head is supported; said support being mounted in said hanger means and shiftable therein in one direction laterally of said passage and into said passage to contact said second terminal with said first terminal and in the opposite direction to disconnect said second terminal from said first terminal and to remove said support and second conductor means completely from said passage; and coengaging means on said landing head and hanger means for turning said landing head to a predetermined angular position in said hanger means to insure alignment between said terminals.

22. In apparatus as defined in claim 17; and means providing a releasable connection between said first conductor means and subsurface device to separate said first conductor means from said device in response to a predetermined tensile pull taken on said first conductor means.

23. In apparatus as defined in claim 17; wherein said subsurface device is an electrically driven pump.

24. In apparatus adapted for use in a well bore having a casing string therein: hanger means at the top of the well bore; a landing head removably supported in said hanger means; a tubing string secured to and depending from said landing head and disposed within the casing string; an electrically operated subsurface device in said tubing string; first electric conductor means connected to said subsurface device and extending upwardly therefrom and externally of the tubing string to said landing head, said conductor means having a first terminal in said landing head; a support; second electric conductor means carried by said support and having a second terminal adapted to be brought into and from contact with said first terminal in response to longitudinal movement of said support relative to said landing head; said support and second conductor means being movable from obstructing relation to said landing head to permit withdrawal of said landing head, tubing string. subsurface device and first conductor means from the well bore and hanger means.

25. in apparatus as defined in claim 24; wherein said subsurface device is a pump.

26. The method of installing or removing electric conducting means at a well bore location for use with an electrically operated subsurface device disposed in the well bore, a hanger being located at the top of the well bore, comprising securing the lower end of a first electric cable to the subsurface device and its upper end to a landing head, said cable having a first terminal, lowering the landing head, electric cable and subsurface device until the subsurface device with the cable attached thereto is located in a desired position in the well bore and with the landing head seating on the hanger; engaging orienting means on said landing head with companion orienting means on said hanger to insure predetermined angular positioning of said landing head and said first terminal in said hanger; and moving a support carrying a second cable having a second terminal into said landing head to contact said second terminal with said first terminal.

27. The method of installing or removing electric conducting means at a well bore location for use with an electrically operated subsurface device disposed in the well bore, a hanger being located at the top of the well bore, comprising securing the lower end of a first electric cable to the subsurface device and its upper end to a landing head, said cable having a first terminal, lowering the landing head, electric cable and subsurface device until the subsurface device with the cable attached thereto is located in a desired position in the well bore and with the lan;ing head seating on the hanger; and moving a support carrying a second cable having a second terminal into said landing head to contact said second terminal with said first terminal; the landing head seating in an axial bore in the hanger, the support being movable into the landing head to a position preventing elevation of said landing head from the hanger bore, and withdrawing the support and second cable from the landing head to disconnect the second terminal from the first terminal and permit upward elevation of said landing head, first cable and subsurface device from the well bore and hanger.

28. The method of installing or removing electric conducting means at a well bore location for use with an electrically operated subsurface device disposed in the well bore, a hanger being located at the top of the well bore, comprising securing the lower end of a first electric cable to the subsurface device and its upper end to a landing head, said cable having a first terminal, lowering the landing head, said cable having a first terminal, lowering the landing head, electric cable and subsurface device until the subsurface device with the cable attached thereto is located in a desired position in the well bore and with the landing head seating on the hanger; and moving a support carrying a second cable having a second terminal into said landing head to contact said second terminal with said first terminal; the landing head seating in an axial bore in the hanger, the support being moved laterally into the axial bore and landing head to a position preventing elevation of said landing head from the hanger bore, and withdrawing the support laterally from the landing head and completely from the hanger bore to disconnect the second terminal from the first terminal and permit upward elevation of said landing head, first cable and subsurface device from the well bore and hanger.

29. The method of installing or removing electric conducting means at a well bore location for use withan electrically operated subsurface device disposed in the well bore, a hanger being located at the top of the well bore, comprising securing the lower end of a first electric cable to the subsurface device and its upper end to a landing head, said cable having a first terminal, lowering the landing head, electric cable and subsurface device until the subsurface device with the cable attached thereto is located in a desired position in the well bore and with the landing head seating on the hanger; and moving a support carrying a second cable having a second terminal into said landing head to contact said second terminal with said first terminal; the landing head seating in an axial bore in the ban er, the support being moved lon itudinally into the landing ead to a position preventing e evation of said landing head from the hanger bore, and withdrawing the support and second cable longitudinally from the landing head to disconnect the second terminal from the first terminal and permit upward elevation of said landing head, first cable and subsurface device from the well bore and hanger.

UNlTED STATES lA'lEN'l OFFLCE CERT ll IQATE U1 CORRECTION Patent No. 3,638,732 Dated February 1;, 1972 lllVClltOI S O FRITZ R m AL It is certified that error appears in the above-identified patent and that said Letters Patent are hereby corrected as shown below:

m1; 10 line I, laid should read said; line 8 (claim 4, line 5) "'aid should read =-=said=-; line 13 (claim 5, line 2) "aid" should read said; line 36 (claim 8, line 12), "a:ld' should read saidg lines 64 and 69 (claim 10;, lines 2 and 7) "aid" (both occurrences) should read =-==said=-=e Column 14, lines 5 and 6, cancel "lowering the larading head, said eable having a first terminal,".

Signed and sealed this 19th day of September-1972.

. (SEAL) Attest:

. i EDWARD N.FLETCHER JR ROBERT GOTTSCHALK Attesting Officer Commissioner of Patents

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Classifications
U.S. Classification166/379, 166/68, 166/368, 166/65.1
International ClassificationE21B33/04, E21B33/035, E21B43/013, H02G15/08, E21B33/03, E21B17/02, E21B43/00
Cooperative ClassificationE21B33/0407, E21B17/028, E21B33/035, E21B17/023
European ClassificationE21B33/035, E21B17/02C, E21B17/02E, E21B33/04E
Legal Events
DateCodeEventDescription
Mar 16, 1987ASAssignment
Owner name: VETCO GRAY INC.,
Free format text: MERGER;ASSIGNORS:GRAY TOOL COMPANY, A TX. CORP. (INTO);VETCO OFFSHORE INDUSTRIES, INC., A CORP. (CHANGED TO);REEL/FRAME:004748/0332
Effective date: 19861217
Feb 5, 1987ASAssignment
Owner name: CITIBANK, N.A.,
Free format text: SECURITY INTEREST;ASSIGNOR:VETCO GRAY INC., A DE. CORP.;REEL/FRAME:004739/0780
Effective date: 19861124
May 1, 1986ASAssignment
Owner name: VETCO OFFSHORE INDUSTRIES, INC., 7135 ARDMORE ROAD
Free format text: ASSIGNMENT OF ASSIGNORS INTEREST.;ASSIGNOR:VETCO OFFSHORE, INC., A CORP. OF DE.;REEL/FRAME:004572/0533
Effective date: 19860421
Sep 29, 1982ASAssignment
Owner name: VETCO OFFSHORE, INC. 5740 RALSTON ST.VENTURA,CA.93
Free format text: ASSIGNMENT OF ASSIGNORS INTEREST.;ASSIGNOR:VETCO INC.;REEL/FRAME:004056/0858
Effective date: 19820922