CA3107031A1 - A braking system and wellbore fluid sealing systems for progressive cavity pump(pcp) drive head - Google Patents
A braking system and wellbore fluid sealing systems for progressive cavity pump(pcp) drive head Download PDFInfo
- Publication number
- CA3107031A1 CA3107031A1 CA3107031A CA3107031A CA3107031A1 CA 3107031 A1 CA3107031 A1 CA 3107031A1 CA 3107031 A CA3107031 A CA 3107031A CA 3107031 A CA3107031 A CA 3107031A CA 3107031 A1 CA3107031 A1 CA 3107031A1
- Authority
- CA
- Canada
- Prior art keywords
- seal
- drive head
- clutch
- wellbore fluid
- pump
- Prior art date
- Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
- Pending
Links
Classifications
-
- F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
- F16—ENGINEERING ELEMENTS AND UNITS; GENERAL MEASURES FOR PRODUCING AND MAINTAINING EFFECTIVE FUNCTIONING OF MACHINES OR INSTALLATIONS; THERMAL INSULATION IN GENERAL
- F16D—COUPLINGS FOR TRANSMITTING ROTATION; CLUTCHES; BRAKES
- F16D57/00—Liquid-resistance brakes; Brakes using the internal friction of fluids or fluid-like media, e.g. powders
- F16D57/06—Liquid-resistance brakes; Brakes using the internal friction of fluids or fluid-like media, e.g. powders comprising a pump circulating fluid, braking being effected by throttling of the circulation
-
- F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
- F16—ENGINEERING ELEMENTS AND UNITS; GENERAL MEASURES FOR PRODUCING AND MAINTAINING EFFECTIVE FUNCTIONING OF MACHINES OR INSTALLATIONS; THERMAL INSULATION IN GENERAL
- F16D—COUPLINGS FOR TRANSMITTING ROTATION; CLUTCHES; BRAKES
- F16D11/00—Clutches in which the members have interengaging parts
- F16D11/14—Clutches in which the members have interengaging parts with clutching members movable only axially
Abstract
Present invention relates to a braking system and a wellbore fluid sealing system for a progressive Cavity Pump (PCP) drive head. A braking system is for controlling the release of torsional energy in a controlled manner in a rod string between a drive head and a downhole rotary pump. A rotary hollow shaft drives a fluid pump through a clutch so that when the top end of the rod string rotates in the normal operation direction, the clutch is in non-contact position and does not run the fluid pump. However, when the top end of the rod string seeks to rotate in the opposite direction, the fluid pump is operated through the clutch engagement to pump fluid from a reservoir and back to the reservoir via a flow control valve for restricting fluid flow. This process results in controlling the rate of rod string backspin speed. A wellbore fluid sealing system is for sealing wellbore fluid from leaking onto the ground during operation. The wellbore fluid sealing system includes a seal housing assembly, a sealing sleeve. The sealing sleeve is rotatable relative to the seal housing assembly. The sealing sleeve is connected to the rod string via a driving connector. Lip seals which are installed inside Seal housing, rest against the rotating sealing sleeve external hardened surface to seal wellbore fluid. Field quick replaceable seal assembly may be installed through the top annular opening formed between hollow rotating main shaft internal bore and the external cylindrical surface of a polish rod, landed, and locked at a desired position to seal crude oil.
Description
Description FIELD OF THE INVENTION
The present invention relates to Progressive Cavity Pump (PCP) drive head improvements on a backspin control braking system and a wellbore fluid sealing system.
BACKGROUND OF THE INVENTION
In the past, many conventional wells were operated by a reciprocating drive called "pumpjack" to lift downhole fluid. Many of these pumpjacks have been replaced by rotary drive progressive cavity pumps to lift fluid. Such rotary pumps are particularly suited for heavy crude oil with sand and water. However, to turn a bottom hole pump through a rod string, surface drive head needs to apply a torque on top of the rod string.
This causes a torsional energy storage between a surface drive head and a bottom hole pump. Whenever there is a power failure or a system needs to be shut down, this stored torsional energy, along with the energy created by the fluid head above the pump, must release itself. Without any control on the rate of backspin speed of the rod string, serious problems may occur, such as backspin speed exceeding safe limits of surface mechanical transmission. Damage the motor, and even cause it to explode.
Top of the rod string extruded portion may bend or may be broken off then flung away due to a sudden centrifugal force.
Without a reliable braking system, the rod string could uncouple, and the outcome would be a high cost of fishing rod string job. Most important issue is the field service personal safety. There are three different backspin braking systems in the market. First is a caliper braking system which is a common braking system in the automobile industry. Second is the use of centrifugal forces to trigger a brake mechanism to brake when back spinning and dis-engage when normal operation through an overrunning clutch. Third is the use of over-running clutch to dis-engage hydraulic fluid pump when normal operation and to engage hydraulic fluid pump when back spinning to control the spinning speed. All three brake systems have a reliability issue and even manufacturers do not know when the braking system needs to be serviced. Fundamentally, all three braking systems have a worn-out issue because of utilizing contact friction as a controlling manner. Cost is for replacing an over-running clutch is high.
Although manufacturers have a program to replace braking pads, it is time consuming and Date Recue/Date Received 2021-01-25
The present invention relates to Progressive Cavity Pump (PCP) drive head improvements on a backspin control braking system and a wellbore fluid sealing system.
BACKGROUND OF THE INVENTION
In the past, many conventional wells were operated by a reciprocating drive called "pumpjack" to lift downhole fluid. Many of these pumpjacks have been replaced by rotary drive progressive cavity pumps to lift fluid. Such rotary pumps are particularly suited for heavy crude oil with sand and water. However, to turn a bottom hole pump through a rod string, surface drive head needs to apply a torque on top of the rod string.
This causes a torsional energy storage between a surface drive head and a bottom hole pump. Whenever there is a power failure or a system needs to be shut down, this stored torsional energy, along with the energy created by the fluid head above the pump, must release itself. Without any control on the rate of backspin speed of the rod string, serious problems may occur, such as backspin speed exceeding safe limits of surface mechanical transmission. Damage the motor, and even cause it to explode.
Top of the rod string extruded portion may bend or may be broken off then flung away due to a sudden centrifugal force.
Without a reliable braking system, the rod string could uncouple, and the outcome would be a high cost of fishing rod string job. Most important issue is the field service personal safety. There are three different backspin braking systems in the market. First is a caliper braking system which is a common braking system in the automobile industry. Second is the use of centrifugal forces to trigger a brake mechanism to brake when back spinning and dis-engage when normal operation through an overrunning clutch. Third is the use of over-running clutch to dis-engage hydraulic fluid pump when normal operation and to engage hydraulic fluid pump when back spinning to control the spinning speed. All three brake systems have a reliability issue and even manufacturers do not know when the braking system needs to be serviced. Fundamentally, all three braking systems have a worn-out issue because of utilizing contact friction as a controlling manner. Cost is for replacing an over-running clutch is high.
Although manufacturers have a program to replace braking pads, it is time consuming and Date Recue/Date Received 2021-01-25
2 difficult in the field. Unfortunately, the over-running clutch replacement must be performed in a shop not in the field. This process adds more burden for oil producers.
The second essential item in a PCP drive head is a well fluid seal assembly.
Generally called a stuffing box. In the field operations, major drive head service is to replace stuffing box seals. Conventional stuffing boxes are mounted below the drive head.
Conventional stuffing boxes are typically separated from the wellhead drive and are mounted in a wellhead frame such that they can be serviced from below the wellhead drive without removing it. A conventional stuffing box uses braided packing that can be replaced manually from side openings while the polished rod stays inside the stuffing box. Since the conventional stuffing boxes seal against the polished rod, which is subject to wear, and due to poor alignment of the polished rod to the stuffing box, leakage becomes somewhat inevitable. Replacing stuffing box seals from the bottom of drive head side openings is time consuming and difficult especially during winter operations. A drive head which has a built-in seal assembly inside the drive head bottom sub has been in the market for years. To replace a seal assembly, the drive head needs to be removed and then replace a stuffing box. Although some drive head seals can be replaced from top of the drive head opening without removal of the drive head to service the stuffing box, it is still time consuming and difficult to replace individual sealing elements and associated parts from a confined top annular opening.
So, most companies are preferred to replace a complete drive head using a lifting device rather than servicing a stuffing box in the field. This operation adds costs on oil producers.
GENERAL DESCRIPTION OF THE INVENTION
One aspect of this invention is to provide a backspin control braking system for use with Progressive Cavity (PC) Pumping system. More precisely, this invention provides a braking mechanical system for avoiding a sudden release of torsional energy stored in a rod string between top of the rod string and a bottom hole pump, and the fluid head above the bottom hole pump on power failure and shut down. Top of the rod string is rotated by torque energy derived from a prime mover, and the bottom of the rod string rotates the bottom hole pump. The braking mechanism comprising:
a) a pinion shaft inserted in the mechanical transmission chain between a drive head main hollow shaft and a hydraulic fluid pump, such that the pinion shaft rotates at Date Recue/Date Received 2021-01-25
The second essential item in a PCP drive head is a well fluid seal assembly.
Generally called a stuffing box. In the field operations, major drive head service is to replace stuffing box seals. Conventional stuffing boxes are mounted below the drive head.
Conventional stuffing boxes are typically separated from the wellhead drive and are mounted in a wellhead frame such that they can be serviced from below the wellhead drive without removing it. A conventional stuffing box uses braided packing that can be replaced manually from side openings while the polished rod stays inside the stuffing box. Since the conventional stuffing boxes seal against the polished rod, which is subject to wear, and due to poor alignment of the polished rod to the stuffing box, leakage becomes somewhat inevitable. Replacing stuffing box seals from the bottom of drive head side openings is time consuming and difficult especially during winter operations. A drive head which has a built-in seal assembly inside the drive head bottom sub has been in the market for years. To replace a seal assembly, the drive head needs to be removed and then replace a stuffing box. Although some drive head seals can be replaced from top of the drive head opening without removal of the drive head to service the stuffing box, it is still time consuming and difficult to replace individual sealing elements and associated parts from a confined top annular opening.
So, most companies are preferred to replace a complete drive head using a lifting device rather than servicing a stuffing box in the field. This operation adds costs on oil producers.
GENERAL DESCRIPTION OF THE INVENTION
One aspect of this invention is to provide a backspin control braking system for use with Progressive Cavity (PC) Pumping system. More precisely, this invention provides a braking mechanical system for avoiding a sudden release of torsional energy stored in a rod string between top of the rod string and a bottom hole pump, and the fluid head above the bottom hole pump on power failure and shut down. Top of the rod string is rotated by torque energy derived from a prime mover, and the bottom of the rod string rotates the bottom hole pump. The braking mechanism comprising:
a) a pinion shaft inserted in the mechanical transmission chain between a drive head main hollow shaft and a hydraulic fluid pump, such that the pinion shaft rotates at Date Recue/Date Received 2021-01-25
3 a consistent speed ratio and direction with respect to the top end of the rod string through a second gear attached to the drive head main hollow shaft, b) a hydraulic pump, c) a clutch between the said pinion shaft and the said hydraulic pump, is connected such that when top end of the rod string rotates in the direction corresponding to normal operation of the downhole pump, the clutch is in non-contact position and does not run the hydraulic pump, but when top end of the rod string rotates in the direction opposite that corresponding to normal operation of the downhole pump, the clutch engages and drives the hydraulic pump, d) a reservoir containing a fluid suitable for hydraulic pump, e) an adjustable flow control valve which is connected to the fluid pump output port through a tubing, whereby the stored energy in the rod string, as energy is released, is made to do the work of pumping fluid through the said flow control valve, thus dissipating the stored energy in a controlled manner.
In another aspect, the present invention provides a seal assembly to seal wellbore fluid for a drive head during operation. The downhole pump implementation comprises a drive head, a PC pump, and a drive string, also a drive head comprising an insertable seal assembly. The insertable seal assembly comprises stationary seal housing assembly, and a sealing sleeve, wherein the said sealing sleeve rotates with the drive string.
In another respect, the present invention provides a method of replacing an insertable seal assembly. The method includes providing a wellhead and a drive system, wherein the drive system comprises a drive head, an insertable sealing assembly, a driving clamp. The method also includes providing a safety clamp (not shown) for securing the weight of the rod string which is mounted under the drive head wellhead flange. The method also includes shutting down the well, securing the weight of the drive rod string by placing the safety clamp below the insertable seal assembly at the surface and holding the drive unit stationary. The method also includes pulling insertable seal assembly upwards relative to the drive unit. After removing the top driving clamp, lifting the insertable seal assembly upwards and removing the insertable seal assembly from the drive head top annular opening.
Date Recue/Date Received 2021-01-25
In another aspect, the present invention provides a seal assembly to seal wellbore fluid for a drive head during operation. The downhole pump implementation comprises a drive head, a PC pump, and a drive string, also a drive head comprising an insertable seal assembly. The insertable seal assembly comprises stationary seal housing assembly, and a sealing sleeve, wherein the said sealing sleeve rotates with the drive string.
In another respect, the present invention provides a method of replacing an insertable seal assembly. The method includes providing a wellhead and a drive system, wherein the drive system comprises a drive head, an insertable sealing assembly, a driving clamp. The method also includes providing a safety clamp (not shown) for securing the weight of the rod string which is mounted under the drive head wellhead flange. The method also includes shutting down the well, securing the weight of the drive rod string by placing the safety clamp below the insertable seal assembly at the surface and holding the drive unit stationary. The method also includes pulling insertable seal assembly upwards relative to the drive unit. After removing the top driving clamp, lifting the insertable seal assembly upwards and removing the insertable seal assembly from the drive head top annular opening.
Date Recue/Date Received 2021-01-25
4 BRIEF DESCRIPTION OF THE DRAWINGS
According to the features recited above, the advantages and objects for the present invention can be more fully understood, certain embodiments of the invention are illustrated in the appended drawings.
FIG.1 is an overall system layout illustrating a drive unit, a rod string, a well head, and a bottom hole pump.
FIG.2 is a drive head.
FIG.3 is a cross-sectional view of a drive head including a wellbore fluid seal assembly, a clutch, a motor support frame, a prime mover, and a drive unit bottom flange.
FIG.4 is a detailed cross-sectional view of a flow control valve.
FIG. 5 is a detailed cross-sectional view of fluid pump pressure port output, a tubing, and a flow control valve.
FIG. 6 is a sectional detail view of a clutch mechanism.
FIG. 7 is a detailed view of a clutch at a dis-engaged position.
FIG. 8 is a detailed view of a clutch at an engaged position.
FIG. 9 is an exploded view of a clutch.
FIG. 10 a mounting relationship between a top mounted seal assembly and a drive head.
FIG. 11 a view top of seal assembly mounted on a main hollow shaft.
FIG. 12 a detailed view of the top of seal assembly mounted on a main hollow shaft.
FIG.13 is a driving connector bottom end flat.
FIG. 14 a detail sectional view of a top mounted seal assembly.
FIG. 15 is a view of sealing sleeve flat.
FIG. 16 is a cross sectional view of a drive head.
FIG. 17 is a cross sectional view of a bottom mounted seal assembly.
Date Recue/Date Received 2021-01-25
According to the features recited above, the advantages and objects for the present invention can be more fully understood, certain embodiments of the invention are illustrated in the appended drawings.
FIG.1 is an overall system layout illustrating a drive unit, a rod string, a well head, and a bottom hole pump.
FIG.2 is a drive head.
FIG.3 is a cross-sectional view of a drive head including a wellbore fluid seal assembly, a clutch, a motor support frame, a prime mover, and a drive unit bottom flange.
FIG.4 is a detailed cross-sectional view of a flow control valve.
FIG. 5 is a detailed cross-sectional view of fluid pump pressure port output, a tubing, and a flow control valve.
FIG. 6 is a sectional detail view of a clutch mechanism.
FIG. 7 is a detailed view of a clutch at a dis-engaged position.
FIG. 8 is a detailed view of a clutch at an engaged position.
FIG. 9 is an exploded view of a clutch.
FIG. 10 a mounting relationship between a top mounted seal assembly and a drive head.
FIG. 11 a view top of seal assembly mounted on a main hollow shaft.
FIG. 12 a detailed view of the top of seal assembly mounted on a main hollow shaft.
FIG.13 is a driving connector bottom end flat.
FIG. 14 a detail sectional view of a top mounted seal assembly.
FIG. 15 is a view of sealing sleeve flat.
FIG. 16 is a cross sectional view of a drive head.
FIG. 17 is a cross sectional view of a bottom mounted seal assembly.
Date Recue/Date Received 2021-01-25
5 FIG.18 is a detailed cross-sectional view of the installation relationship between drive head and the bottom mounted seal assembly.
DETAILED DESCRIPTION OF THE DRAWINGS
The apparatus and methods of the present invention, in the context of downhole pump implementations, provides a sealing of production fluid from the environment using a top or bottom mounted seal assembly and a clutch for a reliable backspin control braking mechanism for safety operation.
The discussion below focuses mainly on a clutch. The clutch has a reliable safety mechanism compared with friction types of clutches due to non-friction transmission features when in normal operation.
FIG. 1 illustrates a known progressive cavity pump installation 10 in accordance with one embodiment of the present invention. The installation includes a typical progressive cavity pump drive head 12, a wellhead 18, a bottom hole pump rotor 28, a stator 25, and a drive rod string 20. The bottom of drive rod 20 is connected to the top of rotor 28 and the top of drive rod (most time called polish rod) 35 is clamped on top of the drive unit using rod clamp 30. A safeguard 40 is installed on top of clamp 30. The drive head supports and drives a drive shaft 54. The polish rod 35 is supported and rotated by means of a polish rod clamp 30, which engages an output shaft 54 of the drive head by a driving connector through milled slots and bosses in both parts. The polish rod 35 rotationally drives a drive string 20, sometimes referred to as "drive rods", which, in turn, drives a progressing cavity pump rotor 28 located at the bottom of the installation to produce well fluids to the surface through the wellhead.
FIG.2 is a belt transmission drive head. It may also be a gear transmission drive head.
FIG. 3 is a sectional view of the drive head. A braking mechanism is illustrated, including a first pinion shaft 107, carrying a clutch below which are 108,109,110 and 115 in accordance with one embodiment of the present invention. The pinion shaft 107 is an elongate shaft parallel with the main hollow shaft 54 and extends through the interior of a reservoir 119. The reservoir has four side walls and a bottom wall. The reservoir is completely sealed by a top cap and filled lubricant oil which completely merges the clutch. A second pinion shaft 112 is parallel with the first pinion 107, and it is connected to a hydraulic braking pump 120.
Date Recue/Date Received 2021-01-25
DETAILED DESCRIPTION OF THE DRAWINGS
The apparatus and methods of the present invention, in the context of downhole pump implementations, provides a sealing of production fluid from the environment using a top or bottom mounted seal assembly and a clutch for a reliable backspin control braking mechanism for safety operation.
The discussion below focuses mainly on a clutch. The clutch has a reliable safety mechanism compared with friction types of clutches due to non-friction transmission features when in normal operation.
FIG. 1 illustrates a known progressive cavity pump installation 10 in accordance with one embodiment of the present invention. The installation includes a typical progressive cavity pump drive head 12, a wellhead 18, a bottom hole pump rotor 28, a stator 25, and a drive rod string 20. The bottom of drive rod 20 is connected to the top of rotor 28 and the top of drive rod (most time called polish rod) 35 is clamped on top of the drive unit using rod clamp 30. A safeguard 40 is installed on top of clamp 30. The drive head supports and drives a drive shaft 54. The polish rod 35 is supported and rotated by means of a polish rod clamp 30, which engages an output shaft 54 of the drive head by a driving connector through milled slots and bosses in both parts. The polish rod 35 rotationally drives a drive string 20, sometimes referred to as "drive rods", which, in turn, drives a progressing cavity pump rotor 28 located at the bottom of the installation to produce well fluids to the surface through the wellhead.
FIG.2 is a belt transmission drive head. It may also be a gear transmission drive head.
FIG. 3 is a sectional view of the drive head. A braking mechanism is illustrated, including a first pinion shaft 107, carrying a clutch below which are 108,109,110 and 115 in accordance with one embodiment of the present invention. The pinion shaft 107 is an elongate shaft parallel with the main hollow shaft 54 and extends through the interior of a reservoir 119. The reservoir has four side walls and a bottom wall. The reservoir is completely sealed by a top cap and filled lubricant oil which completely merges the clutch. A second pinion shaft 112 is parallel with the first pinion 107, and it is connected to a hydraulic braking pump 120.
Date Recue/Date Received 2021-01-25
6 Within the interior of the reservoir 119, the first pinion shaft 107 and the main drive head hollow shaft 54 are interconnected through a second gear 105. In one variant, the first pinion 107 and the second gear 105 may mesh in such a way that the ratio of rotation between the shafts 107 and 54 remains constant but 107 pinion gear rotating direction is opposite. On the first pinion shaft 107, there may be a perpendicular cylindrical hole which accommodates a drive pin 109. The drive pin 109 may be positioned in the center of the perpendicular cylindrical hole by a set screw 255. The first half clutch 108 which has a cylindrical sleeve with helical open slots at a given helical rate, moves up and down driven by the driving pin as pinion shaft 107 rotates clockwise or anti-clockwise.
Further, the first half clutch 108 may have evenly disposed teeth. At least two propellers 110 are interconnected to the first half clutch 108 external surfaces at a given angle. As pinion shaft 107 rotates, the drive pin 109 rotates at the same rate and direction of the pinion shaft 107. The drive pin 109 drives the first half clutch 108 move up and down along opened helical slots due to hydraulic force generated on the propeller surfaces. The up and down movements result in engaging and dis-engaging teeth 113 and 114.
A second half clutch comprising a third gear 115 and at least two evenly positioned clutch teeth, is positioned along pinion shaft axial direction and free rotating relative to pinion shaft 107. The second pinion shaft 112 and the third gear 115 may mesh in such a way that the ratio of rotation between the second pinion shaft 112 and the third gear 115 remains constant but rotating direction is opposite. The second pinion shaft 112 is interconnected to hydraulic braking pump 120.
As explained above, the braking drive chain, in operation, whenever downhole pump is being operated normally, the direction of rotation of the pinion shaft 107 is such that the clutch is in non-contact position and no rotation is transmitted through clutch to the second pinion 112, and therefore no hydraulic fluid is pumped.
However, when the entire pumping system shuts down for any reasons, the rod string 20 may attempt to spin backwards, as the stored torsional energy is released, this may cause rotation of the main shaft 54, which in turn may rotate the shaft 107 through the second gear 105. During this backspin of the rod string 20, the rotational direction of the shaft 107 is such as to power the hydraulic braking pump 120 through clutch and Date Recue/Date Received 2021-01-25
Further, the first half clutch 108 may have evenly disposed teeth. At least two propellers 110 are interconnected to the first half clutch 108 external surfaces at a given angle. As pinion shaft 107 rotates, the drive pin 109 rotates at the same rate and direction of the pinion shaft 107. The drive pin 109 drives the first half clutch 108 move up and down along opened helical slots due to hydraulic force generated on the propeller surfaces. The up and down movements result in engaging and dis-engaging teeth 113 and 114.
A second half clutch comprising a third gear 115 and at least two evenly positioned clutch teeth, is positioned along pinion shaft axial direction and free rotating relative to pinion shaft 107. The second pinion shaft 112 and the third gear 115 may mesh in such a way that the ratio of rotation between the second pinion shaft 112 and the third gear 115 remains constant but rotating direction is opposite. The second pinion shaft 112 is interconnected to hydraulic braking pump 120.
As explained above, the braking drive chain, in operation, whenever downhole pump is being operated normally, the direction of rotation of the pinion shaft 107 is such that the clutch is in non-contact position and no rotation is transmitted through clutch to the second pinion 112, and therefore no hydraulic fluid is pumped.
However, when the entire pumping system shuts down for any reasons, the rod string 20 may attempt to spin backwards, as the stored torsional energy is released, this may cause rotation of the main shaft 54, which in turn may rotate the shaft 107 through the second gear 105. During this backspin of the rod string 20, the rotational direction of the shaft 107 is such as to power the hydraulic braking pump 120 through clutch and Date Recue/Date Received 2021-01-25
7 meshed gear 112, 115, thus causing reservoir oil to be drawn through pump intake (not shown) and discharge pressurized oil to a flow control valve 250 through pressure tube 205.
FIG. 4 and 5, In operation on flow control valve, if a rod string 20 is turning too fast or too slow, then by turning flow control valve handle 223 clockwise or counterclockwise to adjust an orifice 227 in accordance with one embodiment of the present invention.
There is a thread engagement between flow control valve housing 229 and flow control valve stem 219. As the turning handle 223, stem 219 moves forwards or backwards relative to flow control valve housing 229. The pressurised fluid from pump 120 out port 203 is regulated through the orifice 227 and discharged through side ports 213 to reservoir 118. This results in controlling the pump rotating speed.
Furthermore, the rate of rod string backspin speed is controlled. The pressurised fluid is sealed through seals 215, 217 and flow control valve is held by 231, 233, which relates to the reservoir housing 118.
FIG.6, FIG.7, FIG.8, and FIG.9 present details of clutch mechanism in accordance with preferred embodiment of the present invention. The pinion shaft 107 is supported by two upper and lower bearings 121. Whenever pinion shaft gear 107 driven by the main shaft gear 105 rotates at counterclockwise direction 268, cross pin 109 rotates at the same rate of speed and direction. Due to the hydraulic force generated on propeller 110 surfaces, the hydraulic force keeps the first half clutch away from the second half clutch along opened pin helical slots 265 and the pin stops at the lowest slot pin hole. Note that the front tooth angle on the first half clutch formed between surface 258 and surface 285 may be less than 90 and the rear tooth angle on the first half clutch formed between surface 258 and surface 290 may be larger than 90 . This results in upper clutch teeth slide off and the first half clutch may be lifted by hydraulic force generated on propeller surfaces.
Whenever the pinion gear 107 driven by the main shaft gear 105 rotates at clockwise direction 270, the cross pin 109 rotates the same rate of speed and direction.
Due to the hydraulic force generated on the propeller 110 surfaces, the force keeps the first half clutch towards the second half clutch along opened pin helical slots 265 and the pin stops at the top of the slot pin hole. Note that the tooth front angle on the second half clutch formed between surface 278 and surface 280 may be smaller than 90 and the tooth rear angle on the second half clutch formed between surface 278 and surface 275 Date Recue/Date Received 2021-01-25
FIG. 4 and 5, In operation on flow control valve, if a rod string 20 is turning too fast or too slow, then by turning flow control valve handle 223 clockwise or counterclockwise to adjust an orifice 227 in accordance with one embodiment of the present invention.
There is a thread engagement between flow control valve housing 229 and flow control valve stem 219. As the turning handle 223, stem 219 moves forwards or backwards relative to flow control valve housing 229. The pressurised fluid from pump 120 out port 203 is regulated through the orifice 227 and discharged through side ports 213 to reservoir 118. This results in controlling the pump rotating speed.
Furthermore, the rate of rod string backspin speed is controlled. The pressurised fluid is sealed through seals 215, 217 and flow control valve is held by 231, 233, which relates to the reservoir housing 118.
FIG.6, FIG.7, FIG.8, and FIG.9 present details of clutch mechanism in accordance with preferred embodiment of the present invention. The pinion shaft 107 is supported by two upper and lower bearings 121. Whenever pinion shaft gear 107 driven by the main shaft gear 105 rotates at counterclockwise direction 268, cross pin 109 rotates at the same rate of speed and direction. Due to the hydraulic force generated on propeller 110 surfaces, the hydraulic force keeps the first half clutch away from the second half clutch along opened pin helical slots 265 and the pin stops at the lowest slot pin hole. Note that the front tooth angle on the first half clutch formed between surface 258 and surface 285 may be less than 90 and the rear tooth angle on the first half clutch formed between surface 258 and surface 290 may be larger than 90 . This results in upper clutch teeth slide off and the first half clutch may be lifted by hydraulic force generated on propeller surfaces.
Whenever the pinion gear 107 driven by the main shaft gear 105 rotates at clockwise direction 270, the cross pin 109 rotates the same rate of speed and direction.
Due to the hydraulic force generated on the propeller 110 surfaces, the force keeps the first half clutch towards the second half clutch along opened pin helical slots 265 and the pin stops at the top of the slot pin hole. Note that the tooth front angle on the second half clutch formed between surface 278 and surface 280 may be smaller than 90 and the tooth rear angle on the second half clutch formed between surface 278 and surface 275 Date Recue/Date Received 2021-01-25
8 may be bigger than 900. The first half clutch and the second half clutch front teeth angles are the same so that they are fully contact when engaged to transfer the torque.
Once fluid pump 120 starts pumping pressure fluid, torque may be transferred through the clutch teeth engagement and the cross-driving pin 109.
The discussion below focuses mainly on a top or bottom mounted seal assembly.
The principles of present invention also allow for a quick installation or a quick removal of the seal assembly without the need to remove a drive head.
Center of FIG.3 presents a cross-sectional view of a drive head 100 wellbore fluid seal assembly 300 in accordance with one embodiment of the present invention. The seal assembly 300 is installed at the top of the main hollow shaft internal upper location. A
driven sheave 52 is coupled with the main hollow shaft 54 slot 133 to transfer the torque. The main shaft slot 133 allows for torque supplied by prime mover 15 mounted on frame 130 and transfers the torque to the main hollow shaft 54. Note that the main hollow shaft 54 internal diameter is bigger than the seal assembly's biggest external diameter and the bottom of seal housing center tube 145 largest diameter. The bottom of the center tube 145 is slid into the bottom flange 128 top internal cylindrical surface, and the bottom of the center tube 145 is locked by the side locking bolts 125.
At least two side locking bolts lock the center tube to prevent from rotating and moving up and down. Locking bolts are engaged with holding plates 141 through thread 139.
Seal ring 135 seals well bore fluid from leaking to atmosphere.
In removing the seal assembly operation, retract two side clamping bolts by turning 125, the bolts 125 comes out of center tube groove 127, then the center tube 145 with top seal assembly can be pulled out of the drive head main shaft through the main shaft top annular opening which formed between the main hollow shaft internal cylindrical surface and the polish rod external cylindrical surface.
FIG. 10, FIG.11 and FIG.12 present the interference between the top mounted seal assembly and top of the hollow shaft annular opening in accordance with one embodiment of the present invention. A polish rod clamp 30 clamps polish rod through polish rod clamp bolts 316. Clamp slots 311 mates with a driving connector 319 upper boss 317. The driving connector bottom side bosses 321 mate with the main shaft top opening slots 325.
Date Recue/Date Received 2021-01-25
Once fluid pump 120 starts pumping pressure fluid, torque may be transferred through the clutch teeth engagement and the cross-driving pin 109.
The discussion below focuses mainly on a top or bottom mounted seal assembly.
The principles of present invention also allow for a quick installation or a quick removal of the seal assembly without the need to remove a drive head.
Center of FIG.3 presents a cross-sectional view of a drive head 100 wellbore fluid seal assembly 300 in accordance with one embodiment of the present invention. The seal assembly 300 is installed at the top of the main hollow shaft internal upper location. A
driven sheave 52 is coupled with the main hollow shaft 54 slot 133 to transfer the torque. The main shaft slot 133 allows for torque supplied by prime mover 15 mounted on frame 130 and transfers the torque to the main hollow shaft 54. Note that the main hollow shaft 54 internal diameter is bigger than the seal assembly's biggest external diameter and the bottom of seal housing center tube 145 largest diameter. The bottom of the center tube 145 is slid into the bottom flange 128 top internal cylindrical surface, and the bottom of the center tube 145 is locked by the side locking bolts 125.
At least two side locking bolts lock the center tube to prevent from rotating and moving up and down. Locking bolts are engaged with holding plates 141 through thread 139.
Seal ring 135 seals well bore fluid from leaking to atmosphere.
In removing the seal assembly operation, retract two side clamping bolts by turning 125, the bolts 125 comes out of center tube groove 127, then the center tube 145 with top seal assembly can be pulled out of the drive head main shaft through the main shaft top annular opening which formed between the main hollow shaft internal cylindrical surface and the polish rod external cylindrical surface.
FIG. 10, FIG.11 and FIG.12 present the interference between the top mounted seal assembly and top of the hollow shaft annular opening in accordance with one embodiment of the present invention. A polish rod clamp 30 clamps polish rod through polish rod clamp bolts 316. Clamp slots 311 mates with a driving connector 319 upper boss 317. The driving connector bottom side bosses 321 mate with the main shaft top opening slots 325.
Date Recue/Date Received 2021-01-25
9 FIG 13, FIG. 14, and FIG.15 present more details of the internal sealing assembly part relationship. There is a flat 433 on the sealing sleeve 415, it mates with an internal flat 438 in the bottom side of driving connector 319. These two mated flats are for transferring torque. The sealing sleeve rotates with the driving connector 319, and the sealing sleeve axial movement is stopped by snap ring 413.
In operation, torque is transferred from the driven sheave 52 to main shaft 54. With the engagement between shaft slots 325 and driving connector boss 321, and the engagement between the driving connector boss 317 and the polish rod clamp slot 311, the torque is transferred to the top of rod string from main shaft 54. As the center tube 145 is locked on to bottom flange 128, and the top of center tube is connected to seal housing 430 through thread connection 432, the seal housing keeps stationary relative to the rotating sealing sleeve. Collar 427, and collar 425 are two lip seal 421 holding collars. Further, collar 427, collar 421, and backup nut 419 position at least two lip seals on axial direction held by thread connection 435 and locked by locking thread bolt 417 and prevent the sealing sleeve from running out on radial direction. This results in loaded internal seal lips resting against on sealing sleeve 415 external cylindrical hardened surface 434. Wellbore fluid 431 is sealed against the sealing sleeve external surface. If the first lip seal 421 leaked, the wellbore fluid is contained by the second lip seal and seal ring 420.
As mentioned above, the polish rod is clamped by a rod clamp 30 and positioned radially by the centralizing collar 404. There is internal seal ring 405 and external seal ring 407 among polish rod centralizing collar 404 internal, external cylindrical surfaces, and the polish rod external cylindrical surface. centralizing collar 404 keeps polish rod centered to avoid radial runout. It seals wellbore fluid 431 from leaking to the atmosphere.
In the operation of removing the top mounted seal assembly, first step may clamp bottom drive head secure clamp which is not shown herein to hold the weight of the rod string and remove the polish rod clamp, unthread the top holding cap 315 thread. Then the driving connector and the seal sleeve may pull upwards from top annular opening.
Second step is to unlock the bottom flange locking bolt 125 out of groove 127, then using a pulling tool (not shown) to engage with top of the seal housing J groove 316 (in FIG.12 detail B) to pull upwards the entire assembly.
Another Date Recue/Date Received 2021-01-25
In operation, torque is transferred from the driven sheave 52 to main shaft 54. With the engagement between shaft slots 325 and driving connector boss 321, and the engagement between the driving connector boss 317 and the polish rod clamp slot 311, the torque is transferred to the top of rod string from main shaft 54. As the center tube 145 is locked on to bottom flange 128, and the top of center tube is connected to seal housing 430 through thread connection 432, the seal housing keeps stationary relative to the rotating sealing sleeve. Collar 427, and collar 425 are two lip seal 421 holding collars. Further, collar 427, collar 421, and backup nut 419 position at least two lip seals on axial direction held by thread connection 435 and locked by locking thread bolt 417 and prevent the sealing sleeve from running out on radial direction. This results in loaded internal seal lips resting against on sealing sleeve 415 external cylindrical hardened surface 434. Wellbore fluid 431 is sealed against the sealing sleeve external surface. If the first lip seal 421 leaked, the wellbore fluid is contained by the second lip seal and seal ring 420.
As mentioned above, the polish rod is clamped by a rod clamp 30 and positioned radially by the centralizing collar 404. There is internal seal ring 405 and external seal ring 407 among polish rod centralizing collar 404 internal, external cylindrical surfaces, and the polish rod external cylindrical surface. centralizing collar 404 keeps polish rod centered to avoid radial runout. It seals wellbore fluid 431 from leaking to the atmosphere.
In the operation of removing the top mounted seal assembly, first step may clamp bottom drive head secure clamp which is not shown herein to hold the weight of the rod string and remove the polish rod clamp, unthread the top holding cap 315 thread. Then the driving connector and the seal sleeve may pull upwards from top annular opening.
Second step is to unlock the bottom flange locking bolt 125 out of groove 127, then using a pulling tool (not shown) to engage with top of the seal housing J groove 316 (in FIG.12 detail B) to pull upwards the entire assembly.
Another Date Recue/Date Received 2021-01-25
10 option may unscrew thread 430 using a pulling tool and pull upwards. Only the seal housing assembly top portion may be pulled out without the center tube.
Installation process is opposite to the steps described above.
FIG.16, FIG.17, and FIG.18 present a bottom mount seal assembly in accordance with one embodiment of the present invention. Note that most parts are the same compared with the top mounted seal assembly. The sealing sleeve 530 may have the same connection with the driving connector 319 compared with the top mounted seal assembly. There is an external tube 535 which the external tube bottom is connected to backup nut 545 through thread connection 540. At least two lip seals are accommodated inside lip seal holder 425 and 427. Top backup nut 545 threaded into seal housing 555, rests against lip seal holder 425 and 427 to prevent lip seals from moving axial direction and locked by set screw 419. Internal cylindrical surfaces of lip seal holders 425, 427 and top backup nut 545, may constrain the sealing sleeve external cylindrical surface to prevent radial runout so that wellbore fluid is sealed during the sealing sleeve is rotating. There is a stop ring 560 at the bottom of the sealing sleeve 530 and locked by snap locking ring 565. The stop ring prevents seal housing assembly from sliding down during installation and contacts against the bottom of seal housing surface 557 when pulling upwards from the top annular opening.
There may be a gap between the top of external tube 525 and the bottom of the driving connector 520 surface. The gap eliminates interference between these two surfaces during system running. This gap is set during installation by adding a spacer 515.
In the seal assembly removable operation, first step may clamp secure clamps below the drive head to hold the weight of the drive rod string and remove the polish rod clamp 30, un-lock locking bolts 125 (See FIG. 18), and un-thread top cap 410.
With a tool help (not shown), pull connector 319 upward, the entire seal assembly is pulled out from the top annular opening which is formed between the main shaft internal cylindrical surface and the external polish rod cylindrical surface.
In the installation operation, whenever pushing the seal assembly into the bottom flange, the gap between two surface 520 and 525 is eliminated due to free sliding of the seal housing assembly relative to the sealing sleeve, and a resistance between the external seal housing surface and the bottom flange internal mating surface.
As the seal assembly is pushed in and reaches the pre-calculated depth, lock the seal housing by locking bolts 125. Locking bolts are located right above top of the seal housing surface Date Recue/Date Received 2021-01-25
Installation process is opposite to the steps described above.
FIG.16, FIG.17, and FIG.18 present a bottom mount seal assembly in accordance with one embodiment of the present invention. Note that most parts are the same compared with the top mounted seal assembly. The sealing sleeve 530 may have the same connection with the driving connector 319 compared with the top mounted seal assembly. There is an external tube 535 which the external tube bottom is connected to backup nut 545 through thread connection 540. At least two lip seals are accommodated inside lip seal holder 425 and 427. Top backup nut 545 threaded into seal housing 555, rests against lip seal holder 425 and 427 to prevent lip seals from moving axial direction and locked by set screw 419. Internal cylindrical surfaces of lip seal holders 425, 427 and top backup nut 545, may constrain the sealing sleeve external cylindrical surface to prevent radial runout so that wellbore fluid is sealed during the sealing sleeve is rotating. There is a stop ring 560 at the bottom of the sealing sleeve 530 and locked by snap locking ring 565. The stop ring prevents seal housing assembly from sliding down during installation and contacts against the bottom of seal housing surface 557 when pulling upwards from the top annular opening.
There may be a gap between the top of external tube 525 and the bottom of the driving connector 520 surface. The gap eliminates interference between these two surfaces during system running. This gap is set during installation by adding a spacer 515.
In the seal assembly removable operation, first step may clamp secure clamps below the drive head to hold the weight of the drive rod string and remove the polish rod clamp 30, un-lock locking bolts 125 (See FIG. 18), and un-thread top cap 410.
With a tool help (not shown), pull connector 319 upward, the entire seal assembly is pulled out from the top annular opening which is formed between the main shaft internal cylindrical surface and the external polish rod cylindrical surface.
In the installation operation, whenever pushing the seal assembly into the bottom flange, the gap between two surface 520 and 525 is eliminated due to free sliding of the seal housing assembly relative to the sealing sleeve, and a resistance between the external seal housing surface and the bottom flange internal mating surface.
As the seal assembly is pushed in and reaches the pre-calculated depth, lock the seal housing by locking bolts 125. Locking bolts are located right above top of the seal housing surface Date Recue/Date Received 2021-01-25
11 570. Once finished locking the seal housing, pull upwards the driving connector 319 and add cylindrical spacer 515, then lower the driving connector on the spacer. Noted that two driving connector bosses 321 have engaged in shaft slots 325 (FIG.12 detail B). Install top cap 315 by threading it onto top of the hollow shaft 54. The last step Installation is finished by installing rod clamp 30.
Date Recue/Date Received 2021-01-25
Date Recue/Date Received 2021-01-25
Claims (27)
The embodiments of the invention in which an exclusive property or privilege is claimed are defined as follows:
1. a braking assembly for use of a drive head to release torsional energy in controlled manner stored in rod string during shut down or power failure in progressive cavity pump operation, the braking assembly comprising:
a) a first pinion shaft driven by a second gear mounted on a main drive shaft so that the first pinion rotates a consistent speed ratio and direction with respect to the top of rod string;
b) a fluid pump;
c) a reservoir containing a fluid;
d) an adjustable flow control valve connected to the fluid pump output port to regulate the fluid pump rotating speed;
e) a clutch disposed on the first pinion shaft, and the clutch comprises a first half clutch with at least two propellers symmetrically installed on the first clutch external surface, a second half clutch, a cross driving pin, and a third gear;
f) a second pinion shaft connected to the fluid pump, which the third gear and the second pinion meshes together to rotate at a consistent speed and ratio, when the top end of the rod string rotates in the direction corresponding to normal operation of the downhole pump, the clutch is in non-contact position and no pumping work is done by the fluid pump, but when the top end of the rod string rotates in the direction opposite that corresponding to normal operation of the downhole pump, the clutch is engaged and the fluid pump does the work of pumping the fluid out of and then back to the said reservoir against a resistance determined by the setting of the flow control valve;
a) a first pinion shaft driven by a second gear mounted on a main drive shaft so that the first pinion rotates a consistent speed ratio and direction with respect to the top of rod string;
b) a fluid pump;
c) a reservoir containing a fluid;
d) an adjustable flow control valve connected to the fluid pump output port to regulate the fluid pump rotating speed;
e) a clutch disposed on the first pinion shaft, and the clutch comprises a first half clutch with at least two propellers symmetrically installed on the first clutch external surface, a second half clutch, a cross driving pin, and a third gear;
f) a second pinion shaft connected to the fluid pump, which the third gear and the second pinion meshes together to rotate at a consistent speed and ratio, when the top end of the rod string rotates in the direction corresponding to normal operation of the downhole pump, the clutch is in non-contact position and no pumping work is done by the fluid pump, but when the top end of the rod string rotates in the direction opposite that corresponding to normal operation of the downhole pump, the clutch is engaged and the fluid pump does the work of pumping the fluid out of and then back to the said reservoir against a resistance determined by the setting of the flow control valve;
2. The brake assembly for use of the drive head to release torsional energy in PCP
system in claim 1, wherein the first half clutch has at least two evenly disposed engaging teeth which each front tooth angle is less than 900 relatively to clutch center line, and each rear tooth angle is bigger than 90 relatively to the clutch center line.
Date Recue/Date Received 2021-01-25
system in claim 1, wherein the first half clutch has at least two evenly disposed engaging teeth which each front tooth angle is less than 900 relatively to clutch center line, and each rear tooth angle is bigger than 90 relatively to the clutch center line.
Date Recue/Date Received 2021-01-25
3. The brake assembly for use of the drive head to release torsional energy in PCP
system in claim 1, wherein the first half clutch comprises at least two propellers evenly disposed on external cylindrical surface of the first clutch to generate hydraulic forces to move the first half clutch towards or against the second half clutch as the rotating direction changes.
system in claim 1, wherein the first half clutch comprises at least two propellers evenly disposed on external cylindrical surface of the first clutch to generate hydraulic forces to move the first half clutch towards or against the second half clutch as the rotating direction changes.
4. The brake assembly for use of the drive head to release torsional energy in PCP
system in claim 1, wherein there is a driving pin bore on the first pinion shaft perpendicular to the first pinion shaft, further, to dispose a driving pin through the driving pin bore and position the driving pin in the center of the first pinion shaft and locked by a locking bolt through the center bore of the first pinion shaft.
system in claim 1, wherein there is a driving pin bore on the first pinion shaft perpendicular to the first pinion shaft, further, to dispose a driving pin through the driving pin bore and position the driving pin in the center of the first pinion shaft and locked by a locking bolt through the center bore of the first pinion shaft.
5. The brake assembly for use of the drive head to release torsional energy in PCP
system in claim 1, wherein there are at least two open helical slots opened on the first half clutch, and the disposed driving pin passing through open helical slots so that the first half clutch rotates relatively to pinion shaft guided by slots, hence, the first half clutch moves towards or against the second half clutch along slot start and end positions.
system in claim 1, wherein there are at least two open helical slots opened on the first half clutch, and the disposed driving pin passing through open helical slots so that the first half clutch rotates relatively to pinion shaft guided by slots, hence, the first half clutch moves towards or against the second half clutch along slot start and end positions.
6. The brake assembly for use of the drive head to release torsional energy in PCP
system in claim 1, wherein the second half clutch has at least two evenly disposed engaging teeth which each front tooth angle is less than 900 relatively to clutch center line, and each rear tooth angle is bigger than 90 relatively to the clutch center line.
system in claim 1, wherein the second half clutch has at least two evenly disposed engaging teeth which each front tooth angle is less than 900 relatively to clutch center line, and each rear tooth angle is bigger than 90 relatively to the clutch center line.
7. The brake assembly for use of the drive head to release torsional energy in PCP
system in claim 1, where the first clutch teeth numbers are the same as the second teeth numbers and all teeth on the first half clutch and the second half clutch are geometrically identical.
system in claim 1, where the first clutch teeth numbers are the same as the second teeth numbers and all teeth on the first half clutch and the second half clutch are geometrically identical.
8. The brake assembly for use of the drive head to release torsional energy in PCP
system in claim 1, wherein the propellers are symmetrically disposed on the external surface of the first half clutch, and at a certain angle that the hydraulic force generated on propeller surface keeps the first half clutch away from the second half of clutch when the first half clutch rotates in the direction corresponding to normal operation of the downhole pump, but when the first half clutch rotates in the direction opposite that corresponding to normal operation of the downhole pump, the hydraulic force generated by propeller surface keeps the first half clutch moving towards the second half clutch.
Date Recue/Date Received 2021-01-25
system in claim 1, wherein the propellers are symmetrically disposed on the external surface of the first half clutch, and at a certain angle that the hydraulic force generated on propeller surface keeps the first half clutch away from the second half of clutch when the first half clutch rotates in the direction corresponding to normal operation of the downhole pump, but when the first half clutch rotates in the direction opposite that corresponding to normal operation of the downhole pump, the hydraulic force generated by propeller surface keeps the first half clutch moving towards the second half clutch.
Date Recue/Date Received 2021-01-25
9. The brake assembly for use of the drive head to release torsional energy in PCP
system in claim 1, wherein the tooth front surfaces from both the first half clutch and the second half clutch fully contact together to transfer torque when the first pinion shaft rotates in the direction opposite that corresponding to normal operation of the downhole pump, and teeth from the first half clutch and the second half of clutch "slide off" due to tooth rear angle relative to clutch center line bigger than 900 when the pinion shaft rotates in the direction corresponding to normal operation of the downhole pump.
system in claim 1, wherein the tooth front surfaces from both the first half clutch and the second half clutch fully contact together to transfer torque when the first pinion shaft rotates in the direction opposite that corresponding to normal operation of the downhole pump, and teeth from the first half clutch and the second half of clutch "slide off" due to tooth rear angle relative to clutch center line bigger than 900 when the pinion shaft rotates in the direction corresponding to normal operation of the downhole pump.
10. The brake assembly for use of the drive head to release torsional energy in PCP
system in claim 1, wherein the clutch is fully merged in reservoir fluid.
system in claim 1, wherein the clutch is fully merged in reservoir fluid.
11. A top mount seal assembly for use of sealing drive head wellbore fluid in PC pump operation comprising:
a) a housing;
b) a hollow rotatable shaft mounted in the housing and concentrically receiving the said polish rod;
c) a driving connector concentrically received by the said rotatable hollow shaft;
d) a wellhead flange;
e) a top mounted seal assembly concentrically received within the said hollow shaft, and bottom of the seal housing assembly is connected to the top of a center tube and the bottom of the center tube is slid in and secured in a bottom wellhead flange upper opening to seal wellbore fluid;
f) a sealing sleeve connected to the driving connector, and the driving connector transfer torque from the hollow shaft to the said sealing sleeve, and the said sealing sleeve is concentrically received by the top mounted seal assembly;
a) a housing;
b) a hollow rotatable shaft mounted in the housing and concentrically receiving the said polish rod;
c) a driving connector concentrically received by the said rotatable hollow shaft;
d) a wellhead flange;
e) a top mounted seal assembly concentrically received within the said hollow shaft, and bottom of the seal housing assembly is connected to the top of a center tube and the bottom of the center tube is slid in and secured in a bottom wellhead flange upper opening to seal wellbore fluid;
f) a sealing sleeve connected to the driving connector, and the driving connector transfer torque from the hollow shaft to the said sealing sleeve, and the said sealing sleeve is concentrically received by the top mounted seal assembly;
12. The top mounted seal assembly for use of sealing drive head wellbore fluid in PC
pump operation in claim 11, there are at least two spring loaded lip seals disposed inside seal collars concentrically installed inside seal housing and arranged in axial direction with seal lips face downwards and backed up by a tightening collar to keep the spring-loaded lip seals stationary, further the internal seal lips rest against the sealing sleeve external surface to seal wellbore fluid.
Date Recue/Date Received 2021-01-25
pump operation in claim 11, there are at least two spring loaded lip seals disposed inside seal collars concentrically installed inside seal housing and arranged in axial direction with seal lips face downwards and backed up by a tightening collar to keep the spring-loaded lip seals stationary, further the internal seal lips rest against the sealing sleeve external surface to seal wellbore fluid.
Date Recue/Date Received 2021-01-25
13. The top mounted seal assembly for use of sealing drive head wellbore fluid in PC
pump operation in claim 11, the said driving connector, the seal housing assembly, and the sealing sleeve being removable upwardly through the top annular opening formed by internal hollow shaft cylindrical surface and external cylindrical surface of a polish rod after removal of the polish rod clamp and the bottom center tube locking screws located on the top of wellhead flange.
pump operation in claim 11, the said driving connector, the seal housing assembly, and the sealing sleeve being removable upwardly through the top annular opening formed by internal hollow shaft cylindrical surface and external cylindrical surface of a polish rod after removal of the polish rod clamp and the bottom center tube locking screws located on the top of wellhead flange.
14. The top mounted seal assembly for use of sealing drive head wellbore fluid in PC
pump operation in claim 11, the top mounted seal assembly being removable upwardly from the top annular out of drive head without removal of the center tube after unscrewing the thread between top of the center tube and bottom of the seal housing assembly.
pump operation in claim 11, the top mounted seal assembly being removable upwardly from the top annular out of drive head without removal of the center tube after unscrewing the thread between top of the center tube and bottom of the seal housing assembly.
15. The top mounted seal assembly for use of sealing drive head wellbore fluid in PC
pump operation in claim 11, the driving connector upper boss mates with the polish rod clamp bottom slots and the driving collar bottom boss mates with the hollow shaft upper slots to transfer torque from the main hollow shaft to the polish rod clamp, further to the sealing sleeve.
pump operation in claim 11, the driving connector upper boss mates with the polish rod clamp bottom slots and the driving collar bottom boss mates with the hollow shaft upper slots to transfer torque from the main hollow shaft to the polish rod clamp, further to the sealing sleeve.
16. The top mounted seal assembly for use of sealing drive head wellbore fluid in PC
pump operation in claim 11, the driving connector bottom cylindrical bore mates with the sealing sleeve upper cylindrical external surface with a seal ring between them to seal wellbore fluid, and there is a flat from both parts mates and transfer torque from the driving connector to the sealing sleeve.
pump operation in claim 11, the driving connector bottom cylindrical bore mates with the sealing sleeve upper cylindrical external surface with a seal ring between them to seal wellbore fluid, and there is a flat from both parts mates and transfer torque from the driving connector to the sealing sleeve.
17. The top mounted seal assembly for use of sealing drive head wellbore fluid in PC
pump operation in claim 11, there are static seal 0 rings on the seal collars and the tightening collar external cylindrical surface to prevent wellbore fluid from releasing to the atmosphere.
pump operation in claim 11, there are static seal 0 rings on the seal collars and the tightening collar external cylindrical surface to prevent wellbore fluid from releasing to the atmosphere.
18. A bottom mount seal assembly for use of sealing drive head wellbore fluid in PC
pump operation comprising:
a) a housing;
b) a hollow rotatable shaft mounted in the housing and concentrically receiving the said polish rod;
c) a driving connector concentrically received by the said rotatable hollow shaft;
Date Recue/Date Received 2021-01-25 d) a wellhead flange;
e) a bottom mounted seal assembly which top of the seal assembly is connected to an external center tubing and the seal assembly is installed into the bottom wellhead flange upper opening to seal wellbore fluid;
f) a sealing sleeve which top end is connected to bottom of the driving connector, and the driving connector transfer torque from the said hollow rotatable driving shaft to the said sealing sleeve;
pump operation comprising:
a) a housing;
b) a hollow rotatable shaft mounted in the housing and concentrically receiving the said polish rod;
c) a driving connector concentrically received by the said rotatable hollow shaft;
Date Recue/Date Received 2021-01-25 d) a wellhead flange;
e) a bottom mounted seal assembly which top of the seal assembly is connected to an external center tubing and the seal assembly is installed into the bottom wellhead flange upper opening to seal wellbore fluid;
f) a sealing sleeve which top end is connected to bottom of the driving connector, and the driving connector transfer torque from the said hollow rotatable driving shaft to the said sealing sleeve;
19. The bottom mounted seal assembly for use of sealing drive head wellbore fluid in PC pump operation in claim 18, wherein there are at least two lip seals disposed inside the seal collars concentrically installed inside the seal housing and arranged in axial direction with seal lips face downwards and backed up by a tightening collar to keep the lip seals stationary, and the internal seal lips rest against the sealing sleeve external hardened surface to seal well bore fluid.
20. The bottom mounted seal assembly for use of sealing drive head wellbore fluid in PC pump operation in claim 18, the said driving connector, the seal housing assembly, and the sealing sleeve being removed through the top annular opening formed by internal hollow shaft cylindrical surface and external cylindrical surface of polish rod after removal of the polish rod clamp and unscrew bottom locking bolts located on top of the wellhead flange.
21. The bottom mounted seal assembly for use of sealing drive head wellbore fluid in PC pump operation in claim 18, the driving connector is connected to the polish rod clamp one side and the other side connected to the sealing sleeve and transfer torque from the hollow shaft to the polish rod clamp, and at the same time transfer torque to the sealing sleeve.
22. The bottom mounted seal assembly for use of sealing drive head wellbore fluid in PC pump operation in claim 18, there are static seal 0 rings on the seal collars and the tightening collar external cylindrical surface to prevent wellbore fluid from releasing to the atmosphere.
23. The bottom mounted seal assembly for use of sealing drive head wellbore fluid in PC pump operation in claim 18, there is a stop collar disposed on the sealing sleeve and locked by a snap ring, and located below the seal housing assembly, therefore the stop collar brings the seal housing assembly when pull upward the driving connector.
Date Recue/Date Received 2021-01-25
Date Recue/Date Received 2021-01-25
24. The bottom mounted seal assembly for use of sealing drive head wellbore fluid in PC pump operation in claim 18, there is a spacer to prevent the upper surface of the external tube and bottom surface of the driving connector from contacting during operation.
25. The top mounted seal assembly for use of sealing drive head wellbore fluid in PC
pump operation in claim 18, the driving connector upper boss mates with the polish rod clamp bottom slots and the driving connector bottom boss mates with the hollow shaft upper slots to transfer torque from the main hollow shaft to polish rod clamp, further to the drive rod string and the sealing sleeve.
pump operation in claim 18, the driving connector upper boss mates with the polish rod clamp bottom slots and the driving connector bottom boss mates with the hollow shaft upper slots to transfer torque from the main hollow shaft to polish rod clamp, further to the drive rod string and the sealing sleeve.
26. The top mounted seal assembly for use of sealing drive head wellbore fluid in PC
pump operation in claim 18, the driving connector bottom cylindrical bore mates with the sealing sleeve upper external cylindrical surface with 0 ring seal between them to seal wellbore fluid, and there is a flat from both parts mates and transfers the torque from the driving collar to the sealing sleeve.
pump operation in claim 18, the driving connector bottom cylindrical bore mates with the sealing sleeve upper external cylindrical surface with 0 ring seal between them to seal wellbore fluid, and there is a flat from both parts mates and transfers the torque from the driving collar to the sealing sleeve.
27. The bottom mounted seal assembly for use of sealing drive head wellbore fluid in PC pump operation in claim 18, during installation, the top mounted seal assembly is inserted through the top annular opening to a desired position and locked by side locking bolts located on the bottom wellhead flange, due to resistance between the seal assembly external surface and the bottom flange top opening internal mating surfaces, the seal housing slides upwards and top of the external tube surface contact bottom of the driving connector, and the contact is eliminated by pulling the driving connector upwards and add a spacer between the hollow shaft top surface and the driving connector side shoulder bottom surface.
Date Recue/Date Received 2021-01-25
Date Recue/Date Received 2021-01-25
Priority Applications (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CA3107031A CA3107031A1 (en) | 2021-01-25 | 2021-01-25 | A braking system and wellbore fluid sealing systems for progressive cavity pump(pcp) drive head |
Applications Claiming Priority (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CA3107031A CA3107031A1 (en) | 2021-01-25 | 2021-01-25 | A braking system and wellbore fluid sealing systems for progressive cavity pump(pcp) drive head |
Publications (1)
| Publication Number | Publication Date |
|---|---|
| CA3107031A1 true CA3107031A1 (en) | 2022-07-25 |
Family
ID=82482523
Family Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| CA3107031A Pending CA3107031A1 (en) | 2021-01-25 | 2021-01-25 | A braking system and wellbore fluid sealing systems for progressive cavity pump(pcp) drive head |
Country Status (1)
| Country | Link |
|---|---|
| CA (1) | CA3107031A1 (en) |
Cited By (1)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN116104916A (en) * | 2023-04-13 | 2023-05-12 | 无锡市钻通工程机械有限公司 | Automatic clutch power head driven by inner and outer double shafts for drilling machine |
-
2021
- 2021-01-25 CA CA3107031A patent/CA3107031A1/en active Pending
Cited By (1)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN116104916A (en) * | 2023-04-13 | 2023-05-12 | 无锡市钻通工程机械有限公司 | Automatic clutch power head driven by inner and outer double shafts for drilling machine |
Similar Documents
| Publication | Publication Date | Title |
|---|---|---|
| US10087696B2 (en) | Polish rod locking clamp | |
| US5427178A (en) | Tubing rotator and hanger | |
| US5318115A (en) | Casing cutting and retrieving tool | |
| CA2710783C (en) | Pump drive head with stuffing box | |
| CA2601492C (en) | Progressive cavity pump (pcp) drive head stuffing box with split seal | |
| CA2074013A1 (en) | Brake assembly for rotating rod | |
| AU2005205767B2 (en) | Rotating stuffing box with split standpipe | |
| US9869142B2 (en) | Torque anchor for blocking the rotation of a production string of a well and pumping installation equipped with such a torque anchor | |
| US20180195361A1 (en) | Wellhead assembly with integrated tubing rotator | |
| US5370179A (en) | Drive head for rotary down hole pump | |
| WO2004092539A1 (en) | Improved pump drive head with integrated stuffing box and clamp | |
| CA3107031A1 (en) | A braking system and wellbore fluid sealing systems for progressive cavity pump(pcp) drive head | |
| CA2441660C (en) | Downhole pumping system | |
| CA2869668A1 (en) | Bearing apparatus and methods | |
| US3847372A (en) | Drilling fluid saver and safety valve | |
| CN102506100B (en) | Hydraulic brake device | |
| US20070051508A1 (en) | Pump drive head with integrated stuffing box and clamp | |
| US20080257555A1 (en) | Linear Drive Assembly with Rotary Union for Well Head Applications and Method Implemented Thereby | |
| AU2017346962B2 (en) | Sealing/locking rod safety clamp and ram system |