US20050045333A1 - Bearing assembly for a progressive cavity pump and system for liquid lower zone disposal - Google Patents
Bearing assembly for a progressive cavity pump and system for liquid lower zone disposal Download PDFInfo
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- US20050045333A1 US20050045333A1 US10/650,708 US65070803A US2005045333A1 US 20050045333 A1 US20050045333 A1 US 20050045333A1 US 65070803 A US65070803 A US 65070803A US 2005045333 A1 US2005045333 A1 US 2005045333A1
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- housing
- rotor
- pump
- bearing assembly
- plunger
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- 239000007788 liquid Substances 0.000 title claims abstract description 36
- 230000000750 progressive effect Effects 0.000 title abstract description 4
- 230000015572 biosynthetic process Effects 0.000 claims abstract description 32
- 238000010168 coupling process Methods 0.000 claims abstract description 29
- 238000005859 coupling reaction Methods 0.000 claims abstract description 29
- 230000008878 coupling Effects 0.000 claims abstract description 28
- 241000282472 Canis lupus familiaris Species 0.000 claims description 62
- 238000005086 pumping Methods 0.000 claims description 26
- 238000000034 method Methods 0.000 claims description 8
- 239000012530 fluid Substances 0.000 claims description 5
- 238000007789 sealing Methods 0.000 claims description 5
- 230000000452 restraining effect Effects 0.000 claims description 4
- 238000004873 anchoring Methods 0.000 claims description 2
- 238000002347 injection Methods 0.000 claims 2
- 239000007924 injection Substances 0.000 claims 2
- 230000009471 action Effects 0.000 abstract description 9
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- 230000001419 dependent effect Effects 0.000 description 2
- 239000000314 lubricant Substances 0.000 description 2
- 230000001050 lubricating effect Effects 0.000 description 2
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- 230000002147 killing effect Effects 0.000 description 1
- 238000012423 maintenance Methods 0.000 description 1
- 230000013011 mating Effects 0.000 description 1
- 230000007246 mechanism Effects 0.000 description 1
- 230000036316 preload Effects 0.000 description 1
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- 239000010937 tungsten Substances 0.000 description 1
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Classifications
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B23/00—Apparatus for displacing, setting, locking, releasing, or removing tools, packers or the like in the boreholes or wells
- E21B23/004—Indexing systems for guiding relative movement between telescoping parts of downhole tools
- E21B23/006—"J-slot" systems, i.e. lug and slot indexing mechanisms
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/12—Methods or apparatus for controlling the flow of the obtained fluid to or in wells
- E21B43/121—Lifting well fluids
- E21B43/126—Adaptations of down-hole pump systems powered by drives outside the borehole, e.g. by a rotary or oscillating drive
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- Life Sciences & Earth Sciences (AREA)
- Engineering & Computer Science (AREA)
- Geology (AREA)
- Mining & Mineral Resources (AREA)
- Physics & Mathematics (AREA)
- Environmental & Geological Engineering (AREA)
- Fluid Mechanics (AREA)
- General Life Sciences & Earth Sciences (AREA)
- Geochemistry & Mineralogy (AREA)
- Reciprocating Pumps (AREA)
Abstract
A progressive cavity pump pumps liquid downhole to a lower formation past a packer set in a casing of a wellbore. The rotor of the pump is axially restrained by a bearing assembly spaced below the pump for controlling uphole reactive loading on the rotor. Preferably the rotor is releasably coupled to the bearing assembly for release and recovery of the rotor from the bearing assembly. Such a releasable coupling is a latch comprising a plunger telescopically and releasably coupled with a housing using a dog and track arrangement, the dog and track utilizing the telescoping action to actuate the coupling and releasing of the latch.
Description
- This application is a regular application of: U.S. Patent provisional application Ser. No. 60/406,338, filed Aug. 28, 2002, the entirety of which are incorporated herein by reference.
- In one aspect, the invention relates generally to the use of a progressive cavity pump (PC Pump) for pumping water downhole for disposal and more particularly to a bearing package for resisting reactive rotor loads of a PC Pump for pumping water downhole for disposal. In another aspect, the invention relates generally to complementary male/female profiled latch components which are applied in a variety of downhole operations to releasably couple components such as for coupling a pump rotor to a bearing package or drivably coupling a pump rotor to surface through a rod string.
- It has been a long recognized problem that during production of hydrocarbons, particularly from gas wells, liquids, primarily water, accumulate in the wellbore. As the liquid builds at the bottom of the well, a hydrostatic pressure head is built which can become so great as to overcome the natural pressure of the formation or reservoir below, eventually “killing” the well.
- A fluid effluent, including liquid and gas, flows from the formation and through perforations in the casing. Liquid accumulates as a result of condensation falling out of the upwardly flowing stream of gas or from seepage of liquids from the formation itself. To further complicate the process the formation pressure typically declines over time. Once the pressure has declined sufficiently so that production has been adversely affected, or stopped entirely, the well must either be abandoned or rehabilitated. Most often the choice becomes one of economics, wherein the well is only rehabilitated if the value of the unrecovered resource is greater than the costs to recover it.
- Many techniques have been utilized to attempt to remove liquids which have accumulated in the wellbore. Of these many techniques some are focused on lifting liquids uphole to the surface, such as in gas or plunger lift systems. Other techniques have been focused on pumping water below the producing zone and into a lower portion of the formation that can act as a reservoir to accommodate the pumped water. These techniques are typified by arrangements that collect liquids below a conventional uphole-pumping pump, pump them slightly uphole and them route them back downhole through bypass tubing. These arrangements are subject to loss of head pumping failures in attempting to establish suction under low head conditions to pump uphole.
- Described herein is a combination of novel elements which enable convenient and effective implementation of a system of direct pumping of liquid to a lower formation for disposal. In a preferred embodiment, a novel arrangement of a PC Pump is applied for pumping downhole through a packer, the rotor being rotatable yet axially restrained in a novel manner against uphole reactive loading and a novel latch being releasably coupled to the rotor.
- In one aspect of the invention, a PC Pump is used to pump liquid directly downhole for disposal. However, Applicant's recognize that the rotor of the pump must be held down into position in the stator during this operation.
- In one broad aspect of the invention apparatus is located in the casing of a wellbore for injecting liquid to a lower formation with a PC Pump having a rotor and a stator, comprising: a packer set in the casing above the formation and adapted for pumping liquids, from uphole of the packer, downhole through the PC Pump and into the lower formation; and a bearing assembly positioned downhole of the PC Pump and spaced from the stator, a shaft connected to the rotor and bearings for rotatably supporting and axially restraining the rotor to the bearing assembly so that as the PC Pump rotor rotated to pump liquid through the stator from above the packer to the formation below the packer, uphole loads acting on the rotor are restrained through the bearing assembly.
- The apparatus enables operation of a method for injecting liquid from a wellbore into a lower formation comprising anchoring the packer in the wellbore above the lower formation; rotating the rotor for pumping liquids from uphole of the packer downhole through the PC Pump and into the lower formation; and supporting the rotor with a bearing assembly positioned downhole of the PC Pump and spaced from the stator.
- Accordingly, in another aspect of the invention, a bearing assembly is provided for restraining uphole movement of a PC Pump rotor while pumping water downhole for disposal. The bearing assembly comprising a shaft extending through a bore in a housing and having bearings rotatably supporting the shaft from the housing, an uphole seal for sealing between the rotatable shaft and the housing; and a downhole seal for sealing the bore of the housing so as to protectively sandwich the bearings therebetween. Preferably, the uphole seal further comprises a first seal face sealed and rotatable with the shaft and biased to rotatably seal against a second seal face supported by and sealed to the housing. The bearing assembly is preferably pressure equalized having a piston in the bore of the housing and having annular seals therebetween; and a spring biasing the piston downhole so that the piston is sealably slidable in the bore for equalizing pressure between the formation and the bore.
- Further, the rotor is preferably removable for maintenance. There are a variety of mechanisms to releasably couple downhole components including collets and shear devices. Due to the inaccessibility of the downhole location and the need for gross movements to effect actuating movement at the point of coupling, there is a need for a reliable and simple coupling device. As set forth above, one downhole operation which is critically dependent on the ability to releasable couple two downhole wellbore components is a situation wherein a PC Pump rotor is restrained against uphole movement as opposed to the conventional restraint against downhole movement during uphole pumping activities.
- Accordingly, in yet another aspect of the invention, a releasable coupling or latch is provided. While the disclosed embodiments are predominately downhole implementations, the latch can be used as surface as well, for instance, to drivably couple a top drive to a polish rod. Further, the latch has characteristics such as being preferably sufficiently compact to be insertable through the PC Pump's stator. In another downhole pumping situation, large PC Pumps can be suspended at the end of tubing. However, the corresponding and large rotors are too large to insert or remove through the tubing string. Accordingly, in this situation, there is a need for a torque-capable releasable coupling between the drive rod string and the uphole end of a rotor which remains in the stator of the PC Pump.
- A qualifying releasable coupling for each of these scenarios is a telescopically coupled plunger and latch housing having complementation radial dogs and a track which implement downhole and uphole manipulation therebetween to effect an automatic, indexed relative rotation therebetween to alternately lock and release the coupling while further enabling the transmission of torque as desired. The tool is implemented in an alternating on/locked and off/released manner.
- In one broad aspect of the invention apparatus for releasably coupling first and wellbore components, at least one of the first or second wellbore components being capable of rotation in response to applied rotational force, comprises a housing adapted for connection to the first wellbore component and having a bore with a first half of a dog and track arrangement formed thereto having at least one dog; and a plunger adapted for connection to the second wellbore component and being sized to fit telescopically axially into and out of the bore, the plunger having a second half of the dog and track arrangement formed thereto, the track of the dog and track arrangement having at least one entrance to and from a circumferential portion, the circumferential portion bounded by a discontinuous proximal cam, through which the at least one entrance extends, and a distal cam spaced from the proximal cam, so that
-
- in a first action, when the plunger telescopes into the housing, each dog is guided through the at least one entrance into the circumferential portion, coupling the plunger and the housing, each dog contacting the distal cam for causing relative rotation between the housing and the plunger until engaging a first rotational stop out of alignment with the entrance in a first rotationally and axially coupled position, and
- in a second action, when the plunger telescopes out of the housing, each dog contacts the proximal cam for causing relative rotation between the housing and the plunger until engaging a second rotational stop out of alignment with the entrance in a second rotationally and axially coupled position, and
- in a third action, when the plunger telescopes into the housing, each dog contacts the distal cam for causing relative rotation between the housing and the plunger until engaging a third rotational stop substantially aligned with the entrance, so that
- in a fourth action, when the plunger telescopes out of the housing, each dog is guided through the at least one entrance to release the plunger from the housing.
- In another broad aspect, the apparatus enables practicing a novel method for releasably coupling a first wellbore component to a second wellbore component, comprising: telescoping the plunger into the housing for guiding the one or more dogs through corresponding entrances into the track and engaging the track to causing relative rotation between the housing and the plunger until engaging a first rotational stop in a first rotationally and axially coupled position out of alignment with the corresponding entrances, and telescoping the plunger out of the housing for engaging the track and causing relative rotation between the housing and the plunger until engaging a second rotational stop in a second rotationally and axially coupled position out of alignment with the corresponding entrances, and telescoping into the housing for engaging each dog with the track to causing relative rotation between the housing and the plunger until engaging a third rotational stop substantially aligned with the corresponding entrances, and telescoping the plunger out of the housing for guiding each dog through the corresponding entrances to release the plunger from the housing.
- Preferably, the releasable coupling is located between the downhole end of a rotor of a PC Pump and an uphole end of a bearing assembly spaced below the PC Pump.
-
FIG. 1 is a cross-sectional elevation of a wellbore having PC Pump and a bearing assembly accordingly to one embodiment of the invention. -
FIG. 2 is a perspective view of the housing of a bearing assembly of the present invention having a latch housing connected thereto for connection using a latch plunger to a rotor (not shown) of a PC Pump; -
FIG. 3 a is a downhole end view of the bearing assembly housing according toFIG. 2 further detailing showing a snap ring at a lower end of the housing, a hex nut and a lower piston face retained by the snap ring; -
FIG. 3 b is a cross-sectional view of the bearing assembly housing, latch housing and plunger according toFIG. 3 a as sectioned along section lines A-A; -
FIG. 3 c is a cross-sectional view of the latch housing and plunger according toFIG. 3 b taken along section lines B-B; -
FIG. 4 is a perspective view of the latch housing according toFIG. 3 b with a partial cutaway to illustrate the radial profile of a latch dog; -
FIG. 5 a is an end view of a latch housing according toFIG. 4 ; -
FIG. 5 b is a cross-sectional view of the latch housing according toFIG. 5 a taken along section lines A-A and illustrating an axial post at a downhole end for coupling to a shaft of the bearing assembly; -
FIG. 6 a is a downhole end view of a latch plunger adapted for connection to the rotor of a PC Pump, the plunger being adapted for latching with the latch housing and latch dogs according toFIGS. 3 b and 5 b; -
FIG. 6 b is a cross-sectional view according toFIG. 6 a taken along section lines A-A; -
FIG. 6 c is a side view of the latch plunger according toFIG. 6 b; -
FIG. 6 d is a cross-sectional view according toFIG. 6 c along section lines C-C; -
FIG. 6 e is a cross-sectional view according toFIG. 6 c along section lines G-G; -
FIG. 7 a is a perspective view of the latch plunger according toFIG. 6 c; -
FIG. 7 b is a partial perspective view of an upper profiled track and a lower profiled track of the plunger assembly according to the cutaway E ofFIG. 7 a; -
FIG. 7 c is a side view of the upper profiled track according to cutaway F ofFIG. 6 c; -
FIG. 7 d is a partial side view of the lower profiled track according to the cutaway D ofFIG. 7 c; -
FIG. 8 is a roll-out schematic view of the circumferential arrangement of a latch according to one embodiment of the invention. The roll-out illustrates the progressive movement of a dog of the latch housing (only one of three shown for clarity) as the plunger and the lower and upper profiled tracks interact with the latch dog between released, latched, and released once again; -
FIGS. 9 a-c are partial side views illustrating the housing and plunger of another embodiment of the invention, operating according to the principles set forth inFIG. 8 and illustrating the sequence for engaging the latch plunger of a rotor to the latch housing of the bearing assembly where, -
FIG. 9 a illustrates the latch plunger entering a bore of the latch housing, -
FIG. 9 b illustrates the latch plunger being pushed into the latch housing, rotating the latch housing to cause a latch dog to engage the upper latch track, and -
FIG. 9 c illustrates pulling the plunger uphole to cause the latch housing to rotate and the latch dog to lock into the lower profiled track; -
FIGS. 10 a and 10 b together illustrate a cross-sectional view of a wellbore casing according to an embodiment of the invention wherein a stator of a PC Pump is connected to a tubing string and wherein the rotor is installed through the tubing string and into the stator, the lower end of the rotor being latched into a lower bearing assembly for pumping liquid water downhole, the packer, an optional anchor and a one way valve being illustrated in schematic form only; -
FIGS. 11 a and 11 b together illustrate a cross-sectional view of a wellbore casing according to another embodiment of the invention wherein the rotor of a PC Pump, anchored downhole, is lowered into the stator using co-rod, coiled tubing or the like, and is latched into a lower bearing assembly for pumping liquid water downhole; -
FIG. 12 is a perspective view of a male and female latch prior to coupling, the plunger and the housing being arranged for more generic connection with their respective components, threaded ends and wrench flats being provided for both; -
FIG. 13 is a cross-sectional views of the male and female components of the latch in the working and fully set downhole rotated position; -
FIG. 14 is a schematic view illustrating an implementation of the latch for releasably coupling with an oversize rotor for driving the rotor in a pump stator at the end of a tubing string; and -
FIG. 15 is an optional embodiment with the latch housing connected to a rod string and the plunger connected to the top of a PC Pump rotor, all of the description associated withFIG. 8 being applicable if uphole/downhole are inversed. - With reference to the schematic of
FIG. 1 , asystem 10 is provided for lower zone disposal in a well. A PC Pump 11 is located downhole and arranged to pump below apacker 12 to isolate a zone below the pump itself. Conventional rod string is threaded for RH rotation. Causing a PC Pump to pump downwardly without first pumping uphole can be achieved with a downwardly pumping rotor having and opposite helix to conventional rotors so that conventional rod threading and rotation can be maintained. ThePC Pump rotor 13 is restrained from reactive uphole movement with a bearingassembly 14 and coupling means 15 are provided for releasably coupling therotor 13 with the bearingassembly 14. - Each of the bearing
assembly 14, thedisposal system 10 and the coupling means 15 are discussed herein. - Generally, with reference to schematic
FIG. 1 , and to more detailedFIGS. 10 a-11 b, several embodiments of the invention are illustrated for disposing of liquid to a formation below apacker 12. In one embodiment inFIGS. 1 and 10 a-10 b astator 16 of the PC Pump 11 is fit to the bottom of atubing string 17 and positioned downhole belowperforations 18 in thecasing 19 of a cased wellbore of a gas well. As shown, accumulatedliquid 20 can interfere with the perforations and inflow of gas. Tubing perforations 20 b positioned downhole of thecasing perforations 18 enable draining of accumulated liquid into the PC Pump 11. Minimum pumping head issues are obviated by placing the PC Pump suction at the top of the pump for downward pumping. ThePC Pump rotor 13 is suspended from arod string 21 extending downhole in thetubing string 17 to fit operably into thestator 16. Therotor 13 extends through a pup-joint 22 to connect to a bearing assembly. Liquid from the PC Pump is discharged throughperforations 23 in the pup joint 22 for disposal into a lower formation 30 (FIG. 10 b), typically through a one-way valve 31. - The bearing
assembly 14 is spaced and supported from thestator 16 via the pup-joint connection 22 for resisting the loads placed thereon by the rotor. Thestator 16 is typically supported in thecasing 19 with thepacker 12. Use of a convention anchor is optional in conjunction with thepacker 12 or if thepacker 12 is not rotationally supporting thestator 16. - Similarly in the embodiment of
FIGS. 11 a,11 b, a PC Pump is positioned downhole below theperforations 18 in the casing and thecasing 19 itself is used as the gas production tubing to surface. The PC Pump stator or other connected tubing is isolated with thepacker 12 and is anchored to thecasing 19 without the need for a supporting tubing string. - The
packer 12, preferably a hydraulic packer, is set adjacent a bottom of the well above thelower formation 30 into which water can be disposed. The operation of the system is described in greater detail below. - As shown in
FIG. 1 , in use, the downhole-pumpingrotor 13 generates uphole reactive loads. If not restrained, therotor 13 will move uphole to pull free or otherwise damage thestator 16. Accordingly, the rotatingrotor 13 is restrained against uphole movement with the bearingassembly 14. The reactive loads borne by the bearingassembly 14 are resisted through the pup-joint connection 22 to the bottom of thePC Pump stator 16. - Water Disposal
- For implementing an embodiment of the disposal invention, as shown in
FIGS. 10 a-10 b, a bottom packer 12 b, preferably a hydraulic packer, is set adjacent a bottom of a well above alower formation 30 into which liquid such as water can be disposed. Atubing string 17 containing the bearingassembly 14 and latchhousing 60 of the present invention as well as thestator 16 of a PC Pump 11 is lowered into the wellbore above the bottom packer 12 b. Asecond packer 12 is set near the top of the PC Pump 11 to hold thestator 16 andtubing 17 in place. The intake of the PC Pump 11 is positioned below the perforations. Aplunger 61 is attached to arotor 13, preferably by apony rod 21 so as to minimize any effects caused by the eccentric rotation of therotor 13. A series of ports 20 b are formed in thetubing string 17 below theperforations 18 and above the PC Pump 11 to permit water, which is heavier than gas to enter and fall into the pump. The PC Pump is configured to draw the water downhole and through a oneway valve 31 such as that set in bottom packer 12 b. Thus the liquid, disposed of in the higher pressure formation below, cannot return uphole. - The
rotor 12 is lowered into and through thestator 16 until theplunger 61 engages thelatch housing 60 and therotor 12 is locked into position in the bearingassembly 14. Pumping can then begin. - In a second embodiment of the invention, as shown in
FIGS. 11 a-11 b, a lower packer 12 b is set as in the first embodiment. The bearingassembly 14 with astator 16 attached at surface is lowered into the wellbore, below theperforations 18 using coiled tubing or the like (not shown) and is held in place by asecond packer 12 set adjacent an uphole end of the PC Pump 11. A cone inlet 11 a is fit to the inlet of the stator 11 to assist in directing theplunger 61 androtor 12 into the stator. Therotor 13 and attachedplunger 61 are then lowered into the wellbore using co-rod or coiled tubing and therotor 13 is latched to the bearingassembly 14 as described above. Liquid produced through theperforations 18 above the pump falls into the cone inlet 11 a and enters the PC Pump 11. In the embodiment of the invention shown inFIGS. 11 a,11 b, significant costs can be saved as a service rig is not required, due to the elimination of jointed tubing string. All of the operations described in this embodiment can be performed using co-rod or coiled tubing without the need for a service rig. - Bearing Assembly
- With reference to
FIGS. 2, 3 a-c, and 10 b the bearingassembly 14 is provided for preventing uphole movement of therotor 13 of a PC Pump 11 while pumpingliquid 20 downhole for disposal. - As shown in
FIGS. 1,10 b, the bearingassembly 14 does not impede thecasing 19 so that disposed liquid 20 can pass thereby. A bypass of the bearing assembly can be through the assembly itself (not shown) or, as shown, can be around the assembly through anannular passage 32 formed between theassembly 14 and thecasing 19. - As shown in
FIGS. 2 and 3 b, the bearingassembly 14 comprises anon-rotating bearing housing 40 defining abore 41 through which a rotatinginner shaft 42 extends. Anannular passage 32 is formed between thehousing 40 and the casing 19 (seeFIG. 10 b). Thehousing 40 is secured against rotation and relative movement relative to the PC Pump (not shown). - A
latch housing 60 is connected at an uphole end of theinner shaft 42 and is adapted for latching to aplunger 61 adapted for connection to therotor 13 of the PC Pump 11. Theinner shaft 42 is supported for rotation and against reactive axial loading. One or morelower thrust bearings 43 are positioned adjacent a lower end of theshaft 42. One or more upperradial bearings 44 are fit adjacent an upper end of theinner shaft 42. While preferably theupper bearings 44 support radial loading, they may also support axial thrust. Similarly, why it is preferred that thelower bearings 43 primarily support thrust, they may also be specified to support radial loading as well. The lower andupper bearings well liquids 20 with a sealing system. - The
lower thrust bearings 43, such as angular contact ball bearings, are fit to anannular space 45 created between theinner shaft 42 and the non-rotatingouter housing 40. A nut andwasher assembly 46 secure the lower end of theinner shaft 42 to thelower thrust bearings 43 which are rotationally supported through ashoulder 47 formed in theouter housing 40. Theannular space 45 is sealed from the wellbore environment byupper seals lower seal 51. Thelower seal 51 is formed between a spring-biasedlower piston 52 between thelower bearings 43 and theouter housing 40. Thelower seal 51 is a non-rotating seal sealably and slidably fit to the non-rotatingouter housing 40. Thelower piston 52 is spaced downhole of the lower end of theinner shaft 42 creating a reservoir for clean lubricating fluid in fluid communication with theannular space 45 for lubricating thebearings - The
inner shaft 42 is further supported against lateral and radial loading by the upperradial bearings 44 such needle bearings positioned in theannular space 45 adjacent anupper seal housing 53 positioned between the upper seal 50 and theouter housing 40. Theupper seal housing 53 is located above theupper bearings 44. The upper seals 50 a,50 b seal despite relative rotation between theinner shaft 42 and thehousing 40. - The upper seals 50 a,50 b preferably comprise opposing, mirrored tungsten or silica carbide seal faces. A first rotating
upper seal 50 b is connected to theinner shaft 42 by theupper seal housing 53 and a second staticupper seal 50 a is connected to theouter housing 40 below the first rotatingupper seal 50 b. The first rotatingupper seal 50 b is biased towards and rotates upon the second static seal face 50 a in a sealed relationship so as to substantially prevent the loss of lubricant from theannular space 45. - The lower seal's
lower piston 52 acts to equalize pressure within theannular space 45 to be substantially that in the wellbore. Further, thelower piston 52 has apreload spring 54 which allows it to react to small losses of lubricant from the bearing assembly annular space. - As shown in
FIGS. 10 a, 10 b and 3 b, therotor 13 andplunger 61 releasably couple to thelatch housing 60 for restraining therotor 13 thereto and thereby retaining therotor 13 in thePC Pump stator 16 in a proper pumping relationship. - Latch
- In greater detail and with reference to
FIGS. 3 b, 4-7 d, the means 15 for connecting the rotor and bearingassembly 14 is a latch 15 b. The latch is capable of releasably coupling a variety of wellbore components together without the need to specifically rotatably align the cooperating mating components themselves. Further, once latched the latch 15 b can transmit significant torque as well as maintain axial coupling. In one embodiment, the latch 15 b is employed to releasably couple or lock therotor 13 of the PC Pump 11 to the bearingassembly 14. - As shown in
FIG. 3 b, the latch 15 b comprises alatch housing 60 adapted for connection to a first wellbore component such as the bearingassembly 14. As shown in this embodiment, thelatch housing 60 is connected at atop end 62 of the bearing assembly'sshaft 42 through a threaded or other connection for co-rotation therewith. Thelatch housing 60 has abore 63. Theplunger 61 is similarly adapted for connection to the second wellbore component such as a threaded or other connection to the lower end of aPC Pump rotor 13. Theplunger 61 is sized to couple telescopically and axially with the housing'sbore 63. One of either the housing or plunger is capable of at least limited rotation to permit some relative rotation between the plunger and the housing. In this embodiment, the coupling and releasing action of the plunger and the housing impose rotational forces, causing the passive component to rotate. In the PC Pump embodiment, one of therotor 13 or the bearingassembly 14 is capable of rotation, typically the housing freely rotates with the bearing assembly in reaction to a rotational force imposed by the plunger. - As shown in
FIGS. 10 a-11 b, theplunger 61, having a diameter less than an overall diameter of thelatch housing 60, is advantageously connected to therotor 13 for facilitating passage through thestator 16 with minimal interference. Where such diametral restriction is not a factor the relative positions of theplunger 61 and thelatch housing 60 may be reversed. For ease of discussion herein, unless otherwise specified, the context is described with respect to the plunger being the uphole wellbore component. - With reference to
FIGS. 4 and 5 , the latch 15 b operates using guided movement of one ormore dogs 70, which extend radially from one of either thelatch housing 60 or theplunger 61, in atrack 80 which is formed in the complementary and opposing plunger or latchhousing 60 respectively. - In the illustrated embodiment of
FIGS. 3 c,4 and 5 a, one or more dogs 70 (three equidistant circumferentially-spaceddogs 70 shown) extend radially into thebore 63 of the housing with a complementary radially extendingtrack 80 being formed in theplunger 61. InFIGS. 8 and 5 b, each dog has a substantially trapezoidal shape having an upholeleading edge 71 and adownhole trailing edge 72. The leadingedge 71 is angled and the trailingedge 72 is also angled. InFIG. 5 b, the trailingedge 72 is optionally formed as an extended key 73 with substantially parallel side edges 74 while retaining the angled trailingedge 72. - With reference to
FIGS. 6 a-e, theplunger 61 comprises a taperedlower end 62. Best shown onFIG. 6 c-6 e, formed on an outer surface of theplunger 61 is a plurality of radially outwardly raisedsegments 63 spaced sufficiently circumferentially from one another so as to form one ormore entrances 64 corresponding to each of the one or more dogs. Eachentrance 64 to the track permits a correspondingdog 70 to pass axially thereby to thetrack 80. Threedogs 70, requiring corresponding three entrances, automatically distributes loads such as torsional loads. - The
track 80 is adapted to sequentially accept the one ormore dogs 70 through theentrances 64; guide and lock the dogs therein and then release the dogs. Eachentrance 64 leads to a track's circumferential portion 80 c bounded with auphole cam 67, proximal theentrances 64, and adownhole cam 69 spaced from theentrances 64 and from theuphole cam profile 67. The uphole cam is discontinuous, interrupted circumferentially by entrances 64. - The uphole and downhole orientations are for reference only, pertinent for this embodiment, and could be inverted in other embodiments.
- Angled downhole faces 66 of the
segments 63 guide thedogs 70 into theirrespective entrances 64. Uphole faces of the segments form a discontinuousdownhole cam 67, interrupted by theentrances 64. Spaced uphole from thedownhole cam 67 is ashoulder 68 forming anuphole cam 69. The uphole anddownhole cams dogs 70 therebetween. - The
downhole cam 67 guides each dog's trailingedge 72 and the uphole cam guides each dogs' leadingedge 71 through the track's circumferential portion 80 c. Thetrack 80 enables alternating theplunger 61 between a coupled position and a released position. The uphole and downhole cams are formed with angled faces complementary to each dog's leading and trailing edges respectively. - The plunger and latch housing are in a coupled position occurs in at least one instance when the
plunger 61 is being pulled axially way from thelatch housing 60 wherein each dog's trailingedge 72 engages the downhole cam 67 (tensile forces acting between theplunger 61 and the latch housing 60). The plunger and latch housing can be locked in a second instance when theplunger 61 is engaged fully into thelatch housing 60 and each dog's leadingedge 71 engages the uphole cam 69 (compressive forces acting between theplunger 61 and the latch housing 60). - More specifically, and with reference to the rolled-out view of the
plunger 61 and latch housing inFIG. 8 and the exploded views ofFIGS. 9 a-9 c, the sequence of operation on onetypical dog 70 is illustrated as follows. Theplunger 61 and attached rotor (not shown) are lowered through the wellbore and stator until the plunger encounters thelatch housing 60. - As shown at A, in a first action, the
plunger 61 is stabbed into the housing (FIGS. 8,9 a). Downhole force applied to theplunger 61 results in engagement of each dog's leadingedge 71 with each segment's angleddownhole face 66 causing relative rotation of thelatch housing 60 andplunger 61, typically causing thelatch housing 60 to rotate sufficiently to permit thedogs 70 to align with and pass axially through eachentrance 64, at B, and into the circumferential portion 80 c between the uphole anddownhole cams - With reference to
FIGS. 8, 9 b, eachdog 70 engages theuphole cam 69 for enabling indexed relative rotation from B to C, and misaligning eachdog 70 from anentrance 64 so that the dogs cannot be directly released from the circumferential track portion 80 c. Relative rotation stops when thedog 70 engages a firstrotational stop 81 formed in theuphole cam 69. At C, the leadingedge 71 of eachdog 70 is positioned and restrained in a first coupled position for locking theplunger 61 into compressive coupling with the latch housing. Torque applied by theplunger 61 is capable of driving thelatch housing 60. Typically, arod string 21 is threadably connected and is capable of drivable RH rotation without unthreading. Accordingly, in most instances, the rotational stops and angled faces of the uphole and downhole cams are arranged so as to provide driving surfaces. The orientation of angles is dependent on which of the plunger and housing are driving and which is being driven. - With reference to
FIGS. 8, 9 c, upon a second and subsequent uphole action from C to D of therotor 13 andplunger 61, such as during downhole pumping, theplunger 61 moves uphole relative to thedogs 70 to D, wherein the trailingedges 72 of thedogs 70 engage thedownhole cam 67, guiding eachdog 70 through indexed relative rotation to a secondrotational stop 82 so as to position and restrain each dog's trailingedge 72 in a second coupled position for locking theplunger 61 in axially tensile coupling with thelatch housing 60. In the embodiment of the PC Pump 11 androtor 13, this is the operational mode wherein therotor 13 imposes tensile loads for co-rotation with thelatch housing 60, such loads being further borne or restrained by the bearingassembly 14. In this mode, theplunger 61, while under tensile loading can also rotatably drive thelatch housing 60. - In
FIG. 8 , one generic embodiment of adog 70 anddownhole cam 67 are shown. This embodiment permits application of torque in one direction only as the first and second rotation stops 81,82 are unidirectional. In an optional embodiment, as shown inFIGS. 5 b,6 c and 9 c secondrotational stop 82 is a pocket 82 p forming a bidirectional stop, having axial faces 77 for engaging theextended key 73, with itsparallel edges 74, in both directions. This arrangement enables torque in both directions. Further, theextended key 73 provides greater surface area and greater torque capability. - In a third action from D to E, as shown further in the general case of
FIG. 8 , when it is desirable to manipulate theplunger 61 to the released position such as to disengage therotor 13 from the bearingassembly 14 and to trip the rotor out of the wellbore, one applies set down or downhole force to move theplunger 61 downhole, guiding each dog's leadingedge 71 for contact with theuphole cam 69 at E, causing indexed relative rotation to a thirdrotational stop 83 which misaligns eachdog 70 from the secondrotational stop 82 and aligns eachdog 70 with anangled discharge face 78 on each segment'sdownhole cam 67. - In a fourth action, at F, uphole movement of the
plunger 61 aligns eachdog 70 once again with eachentrance 64 for release of each dog from thetrack 80 wherein eachdog 70 and theplunger 61 telescope out of thelatch housing 60 to be released at G. - Turning to
FIG. 12 , in a another more universal embodiment of a releasable coupling, alatch assembly 89 is illustrated comprising the describedplunger 61 and thelatch housing 60. Theplunger 61 is adapted with a moregeneric connector 90 having, threaded ends 91 andwrench flats 92 being provided. Similarly, thelatch housing 60 is similarly fitted with threaded ends 93 andwrench flats 94. In greater detail inFIGS. 13 a-13 c, such as generic latching assembly is provided illustrating the equivalent implementation of thedogs 70,segments 63 and cam profiles 67,69 although the uphole and downhole cam designations need not apply, the assembly being operable in either orientation. - With reference to
FIG. 14 , an implementation of thelatch assembly 89 is illustrated in a PC Pump situation which could apply thelatch assembly 89 in either orientation whether the pump is pumping liquids uphole or downhole. There is no longer any requirement to connect the rotor to any specific one of the well components as both theplunger 61 and latchhousing 60 remain above the PC Pump and are not diameter-restricted. In this embodiment, thelatch assembly 89 is required to convey torque from thedrive string 21 to the rotor. As shown inFIG. 15 , in a further illustration of the flexibility of the latch invention, theplunger 61 is shown as depending from thedrive string 21 and thelatch housing 60 is connected to therotor 13.
Claims (17)
1. Apparatus in the casing of a wellbore for injecting liquid to a lower formation with a PC Pump having a rotor, comprising:
a packer set in the casing above the formation and adapted for pumping liquids, from uphole of the packer, downhole through the PC Pump and into the lower formation; and
a bearing assembly positioned downhole of the PC Pump and spaced from the stator, a shaft connected to the rotor and bearings for rotatably supporting and axially restraining the rotor to the bearing assembly so that as the PC Pump rotor rotated to pump liquid through the stator from above the packer to the formation below the packer, uphole loads acting on the rotor are restrained through the bearing assembly.
2. The apparatus of claim 1 wherein the bearing assembly further comprises a releasable coupling between the shaft and the rotor.
3. The apparatus of claim 1 wherein the releasable coupling comprises:
a first connection depending from the rotor;
a second connection extending from the shaft; and
cooperative means between the first and second connections.
4. The apparatus of claim 3 wherein a pony shaft is connected between the first and second connection.
5. The apparatus of claim 3 wherein
the second connection further comprises a housing having a bore; and
the first connection further comprises a plunger so that when the plunger engages the bore of the housing the first and second connection become coupled.
6. The apparatus of claim 5 further wherein the plunger and the housing form a latch operable between two positions:
a first position wherein the first and second connections are coupled; and
a second position wherein the first and second connections are released.
7. The apparatus of claim 6 wherein the latch further comprises:
one or more dogs formed in the bore of the housing, and
a track formed on the plunger and operable with a first axial movement to capture the dog for coupling the first and second connections and operable with a second axial movement to release the one or more dogs for uncoupling the first and second connections.
8. The apparatus of claim 6 wherein the latch further comprises:
one or more dogs on the plunger; and
a track formed in the bore of the housing and operable with a first axial movement to capture the dog for connecting the first and second connections and operable with a second axial movement to release the one or more dogs for uncoupling connecting the first and second connections.
9. The apparatus of claim 6 further comprising a pup-joint spacing the stator from the bearing assembly and having perforations formed therein for directing pumped fluids into the wellbore for injection into the lower formation.
10. The apparatus of claim 9 further comprising a one-way valve located below the pup-joint perforations and above the lower formation.
11. The apparatus of claim 1 wherein the bearings of the bearing assembly is sealed from the pumped liquids.
12. The apparatus of claim 11 wherein the shaft extends through a bore in the housing and the bearings rotatably support the shaft from the housing, the bearing assembly further comprising:
an uphole seal for sealing between the rotatable shaft and the housing; and
a downhole seal for sealing the bore of the housing so as to protectively sandwich the bearings therebetween.
13. The apparatus of claim 11 wherein:
the uphole seal further comprises a first seal face sealed and rotatable with the shaft and biased to rotatably seal against a second seal face supported by and sealed to the housing.
14. The apparatus of claim 11 wherein the downhole seal further comprises:
a piston in the bore of the housing and having annular seals therebetween; and
a spring biasing the piston downhole so that the piston is sealably slidable in the bore for equalizing pressure between the formation and the bore.
15. The apparatus of claim 1 further comprising a pup-joint spacing the stator from the bearing assembly and having perforations formed therein for directing pumped fluids into the wellbore for injection into the lower formation.
16. The apparatus of claim 15 further comprising a one-way valve located below the pup-joint perforations and above the lower formation.
17. A method for injecting liquid from a wellbore into a lower formation with a PC Pump having a rotor and a stator, comprising:
anchoring the packer in the wellbore above the lower formation;
rotating the rotor for pumping liquids from uphole of the packer downhole through the PC Pump and into the lower formation; and
supporting the rotor with a bearing assembly positioned downhole of the PC Pump and spaced from the stator.
Priority Applications (1)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
US10/650,708 US20050045333A1 (en) | 2003-08-29 | 2003-08-29 | Bearing assembly for a progressive cavity pump and system for liquid lower zone disposal |
Applications Claiming Priority (1)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
US10/650,708 US20050045333A1 (en) | 2003-08-29 | 2003-08-29 | Bearing assembly for a progressive cavity pump and system for liquid lower zone disposal |
Publications (1)
Publication Number | Publication Date |
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US20050045333A1 true US20050045333A1 (en) | 2005-03-03 |
Family
ID=34217232
Family Applications (1)
Application Number | Title | Priority Date | Filing Date |
---|---|---|---|
US10/650,708 Abandoned US20050045333A1 (en) | 2003-08-29 | 2003-08-29 | Bearing assembly for a progressive cavity pump and system for liquid lower zone disposal |
Country Status (1)
Country | Link |
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US (1) | US20050045333A1 (en) |
Cited By (4)
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US20090032245A1 (en) * | 2007-08-03 | 2009-02-05 | Zupanick Joseph A | Flow control system having a downhole rotatable valve |
US20090229831A1 (en) * | 2008-03-13 | 2009-09-17 | Zupanick Joseph A | Gas lift system |
WO2014102717A2 (en) * | 2012-12-26 | 2014-07-03 | Serinpet Ltda. Representaciones Y Servicios De Petroleos | Artificial lifting system with base-mounted progressive cavity motor for extracting hydrocarbons |
CN109899035A (en) * | 2019-04-15 | 2019-06-18 | 成都百胜野牛科技有限公司 | Plunger operating device |
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US7789157B2 (en) | 2007-08-03 | 2010-09-07 | Pine Tree Gas, Llc | System and method for controlling liquid removal operations in a gas-producing well |
US7753115B2 (en) * | 2007-08-03 | 2010-07-13 | Pine Tree Gas, Llc | Flow control system having an isolation device for preventing gas interference during downhole liquid removal operations |
US20090032262A1 (en) * | 2007-08-03 | 2009-02-05 | Zupanick Joseph A | Flow control system having an isolation device for preventing gas interference during downhole liquid removal operations |
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US20090032244A1 (en) * | 2007-08-03 | 2009-02-05 | Zupanick Joseph A | Flow control system having an isolation device for preventing gas interference during downhole liquid removal operations |
US7789158B2 (en) | 2007-08-03 | 2010-09-07 | Pine Tree Gas, Llc | Flow control system having a downhole check valve selectively operable from a surface of a well |
US20090050312A1 (en) * | 2007-08-03 | 2009-02-26 | Zupanick Joseph A | Flow control system having a downhole check valve selectively operable from a surface of a well |
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US8162065B2 (en) | 2007-08-03 | 2012-04-24 | Pine Tree Gas, Llc | System and method for controlling liquid removal operations in a gas-producing well |
US8528648B2 (en) | 2007-08-03 | 2013-09-10 | Pine Tree Gas, Llc | Flow control system for removing liquid from a well |
US20090229831A1 (en) * | 2008-03-13 | 2009-09-17 | Zupanick Joseph A | Gas lift system |
US8276673B2 (en) | 2008-03-13 | 2012-10-02 | Pine Tree Gas, Llc | Gas lift system |
WO2014102717A2 (en) * | 2012-12-26 | 2014-07-03 | Serinpet Ltda. Representaciones Y Servicios De Petroleos | Artificial lifting system with base-mounted progressive cavity motor for extracting hydrocarbons |
WO2014102717A3 (en) * | 2012-12-26 | 2014-11-27 | Serinpet Ltda. Representaciones Y Servicios De Petroleos | Artificial lifting system with base-mounted progressive cavity motor for extracting hydrocarbons |
CN109899035A (en) * | 2019-04-15 | 2019-06-18 | 成都百胜野牛科技有限公司 | Plunger operating device |
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Legal Events
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